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ENTERGY MISSISSIPPI, LLC - Quarter Report: 2020 September (Form 10-Q)

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__________________________________________________________________________________________
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q
(Mark One)
☑QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2020
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.
1-11299ENTERGY CORPORATION1-35747ENTERGY NEW ORLEANS, LLC
(a Delaware corporation)
639 Loyola Avenue
New Orleans, Louisiana 70113
Telephone (504) 576-4000
(a Texas limited liability company)
1600 Perdido Street
New Orleans, Louisiana 70112
Telephone (504) 670-3700
72-122975282-2212934
1-10764ENTERGY ARKANSAS, LLC1-34360ENTERGY TEXAS, INC.
(a Texas limited liability company)
425 West Capitol Avenue
Little Rock, Arkansas 72201
Telephone (501) 377-4000
(a Texas corporation)
10055 Grogans Mill Road
The Woodlands, Texas 77380
Telephone (409) 981-2000
83-191866861-1435798
1-32718ENTERGY LOUISIANA, LLC1-09067SYSTEM ENERGY RESOURCES, INC.
(a Texas limited liability company)
4809 Jefferson Highway
Jefferson, Louisiana 70121
Telephone (504) 576-4000
(an Arkansas corporation)
1340 Echelon Parkway
Jackson, Mississippi 39213
Telephone (601) 368-5000
47-446964672-0752777
1-31508ENTERGY MISSISSIPPI, LLC
(a Texas limited liability company)
308 East Pearl Street
Jackson, Mississippi 39201
Telephone (601) 368-5000
83-1950019
__________________________________________________________________________________________


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Securities registered pursuant to Section 12(b) of the Act:
RegistrantTitle of ClassTrading
Symbol		Name of Each Exchange
on Which Registered
Entergy Corporation
Common Stock, $0.01 Par Value
ETR
New York Stock Exchange
Common Stock, $0.01 Par Value
ETR
NYSE Chicago, Inc.
 
 
 
Entergy Arkansas, LLC
Mortgage Bonds, 4.875% Series due September 2066
EAI
New York Stock Exchange
 
 
 
Entergy Louisiana, LLC
Mortgage Bonds, 5.25% Series due July 2052
ELJ
New York Stock Exchange
 
Mortgage Bonds, 4.70% Series due June 2063
ELU
New York Stock Exchange
Mortgage Bonds, 4.875% Series due September 2066
ELC
New York Stock Exchange
 
 
 
Entergy Mississippi, LLC
Mortgage Bonds, 4.90% Series due October 2066
EMP
New York Stock Exchange
 
 
 
Entergy New Orleans, LLC
Mortgage Bonds, 5.0% Series due December 2052
ENJ
New York Stock Exchange
Mortgage Bonds, 5.50% Series due April 2066
ENO
New York Stock Exchange
 
 
 
Entergy Texas, Inc.
5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)
ETI/PR
New York Stock Exchange

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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 ☑ No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted 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 such files).  Yes ☑ No ☐

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 filerAccelerated
filer		Non-accelerated filerSmaller
reporting
company		Emerging
growth
company
Entergy Corporationü
Entergy Arkansas, LLCü
Entergy Louisiana, LLCü
Entergy Mississippi, LLCü
Entergy New Orleans, LLCü
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. ☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑
Common Stock OutstandingOutstanding at October 30, 2020
Entergy Corporation($0.01 par value)200,232,522

Entergy Corporation, Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, 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, 2019 and the Quarterly Reports for Form 10-Q for the quarters ended March 31, 2020 and June 30, 2020, filed by the individual registrants with the SEC, and should be read in conjunction therewith.


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TABLE OF CONTENTS
Page Number
Part I. Financial Information
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy Arkansas, LLC and Subsidiaries
Entergy Louisiana, LLC and Subsidiaries
i
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Page Number
Entergy Mississippi, LLC
Entergy New Orleans, LLC and Subsidiaries
Entergy Texas, Inc. and Subsidiaries
System Energy Resources, Inc.
Part II. Other Information
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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 and in this report, (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;
•continuing 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, the MISO-wide base rate of return on equity allowed or any MISO-related charges and credits required by the FERC, 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 return on equity criteria, 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 or actual shutdown and sale of each of the 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 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 changing regulatory requirements, emerging operating and industry issues, and the commitment of substantial human and capital resources required for the safe and reliable 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;

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FORWARD-LOOKING INFORMATION (Continued)

•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 and 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;
•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 and other regulated air emissions, heat and other regulated discharges to water, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with 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, domestic purchase requirements, or energy policies;
•the effects of full or partial shutdowns of the federal government or delays in obtaining government or regulatory actions or decisions;
•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 (including from Hurricane Laura, Hurricane Delta, and Hurricane Zeta), 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, as well as any related unplanned outages;
•the risk that an incident at any nuclear generation facility in the U.S. could lead to the assessment of significant retrospective assessments and/or retrospective insurance premiums as a result of Entergy’s participation in a secondary financial protection system, a utility industry mutual insurance company, and industry self-insurance programs;
•effects of climate change, including the potential for increases in extreme weather events and 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, including completion of projects timely and within budget and to obtain the anticipated performance or other benefits, and its 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 Tax Cuts and Jobs Act and its intended and unintended consequences on financial results and future cash flows;
•the effects of Entergy’s strategies to reduce tax payments;
•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;
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FORWARD-LOOKING INFORMATION (Concluded)

•changes in inflation and interest rates;
•the effects of litigation and government investigations or proceedings;
•changes in technology, including (i) Entergy’s ability to implement new or emerging technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, renewable energy, energy efficiency, demand side management and other measures that reduce load and government policies incentivizing development of the foregoing, and (iii) competition from other companies offering products and services to Entergy’s customers based on new or emerging technologies or alternative sources of generation;
•Entergy’s ability to effectively formulate and implement plans to reduce its carbon emission rate and carbon emissions, and the potential impact on its business of attempting to achieve such objectives;
•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;
•the effects of a global event or pandemic, such as the COVID-19 global pandemic, including economic and societal disruptions; volatility in the capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available bank credit facilities); reduced demand for electricity, particularly from commercial and industrial customers; increased or unrecoverable costs; supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; impacts to Entergy’s workforce availability, health, or safety; increased cybersecurity risks as a result of many employees telecommuting; increased late or uncollectible customer payments; regulatory delays; executive orders affecting, or increased regulation of, Entergy’s business; changes in credit ratings or outlooks as a result of any of the foregoing; or other adverse impacts on Entergy’s ability to execute on its business strategies and initiatives or, more generally, on Entergy’s results of operations, financial condition, and liquidity;
•Entergy’s ability to attract and retain talented management, directors, and employees with specialized skills;
•Entergy’s ability to attract, retain, and manage an appropriately qualified workforce;
•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;
•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 and sales of 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;
•the potential for the factors listed herein to lead to the impairment of long-lived assets; and
•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that Entergy may undertake.
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DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:
Abbreviation or AcronymTerm
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
COVID-19
The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
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
Form 10-K
Annual Report on Form 10-K for the calendar year ended December 31, 2019 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 AcronymTerm
Indian Point 2
Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2020
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)
Nelson Unit 6
Unit No. 6 (coal) of the Nelson Steam Electric Generating Station, 70% of which is co-owned by Entergy Louisiana (57.5%) and Entergy Texas (42.5%) and 10.9% of which is owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
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
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), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2019 and was sold in August 2019
PPA
Purchased power agreement or power purchase agreement
PUCT
Public Utility Commission of Texas
Registrant Subsidiaries
Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, 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
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DEFINITIONS (Concluded)
Abbreviation or AcronymTerm
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
Vermont Yankee
Vermont Yankee Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in December 2014 and was disposed of in January 2019
Waterford 3
Unit No. 3 (nuclear) of the Waterford Steam Electric Station, owned 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 and 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.

The COVID-19 Pandemic

The COVID-19 pandemic and the measures to control it have adversely affected economic activity and conditions worldwide and have affected the demand for the products and services of many businesses in Entergy’s service area. Entergy expects a decline in sales volume for the year 2020 due to the COVID-19 pandemic, especially in the commercial and industrial sectors. In addition, Entergy has experienced negative changes to its customers’ payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. These negative changes include an increase in uncollectible accounts.

Entergy provides critical services to its customers and has implemented its comprehensive incident response plan, which contemplates major events such as storms or pandemics. Entergy’s focus during the pandemic has been on the safety and wellness of its employees; providing safe, reliable service for its customers; analyzing and addressing the financial effects of the COVID-19 pandemic; and continuing its plans for the future. Entergy implemented precautionary measures for safety on and off the job for employees and contractors working at plants and in the field and implemented telecommuting practices for employees who can work from home. Entergy temporarily suspended service disconnections for customers and is working with regulators to address routine and non-routine matters and allow continuation of capital spending plans. The Utility operating companies have received accounting orders to defer costs associated with COVID-19. To date, Entergy has not had material effects to its major projects or capital spending plans. Entergy is working with suppliers and contractors for continued availability of resources, equipment, and supplies to keep operations and major projects going forward and on schedule. Entergy is implementing expense-related spending reductions in 2020, which it does not expect to affect safety or service reliability, in order to offset some of the financial effects of the COVID-19 pandemic. Beginning in March 2020 the Utility operating companies issued a total of $2.51 billion of long-term mortgage bonds, Entergy Corporation issued $2.0 billion of senior notes, and Entergy Arkansas and Entergy Mississippi renewed their short-term credit facilities. In addition to cash on hand, Entergy’s sources of liquidity are outlined in “Capital Structure and Resources” and in Note 4 to the financial statements herein.

Although Entergy has taken these actions in response to the COVID-19 pandemic, uncertainty exists regarding the full depth and length of the effects of COVID-19 on Entergy’s sales volume, revenue, collections and cash flows, expenses, liquidity, and capital needs. Entergy will continue to monitor actively the COVID-19 pandemic and related developments affecting its workforce, customers, suppliers, operations, and financial condition.


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Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis

Hurricane Laura

In August 2020, Hurricane Laura caused severe damage to the Entergy distribution and transmission systems across Louisiana and Texas. The storm resulted in widespread power outages and as a result of the storm’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Laura are currently estimated to be in the range of $1.5 billion to $1.7 billion. The majority of the costs were incurred by Entergy Louisiana and Entergy Texas. Entergy also expects Utility revenues in 2020 to be adversely affected, primarily due to power outages resulting from the hurricane. Entergy is considering all available avenues to recover storm-related costs from Hurricane Laura, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $205 million and construction work in progress of approximately $1.295 billion. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

Hurricane Delta

In October 2020, Hurricane Delta caused significant damage to portions of Entergy's service area in Louisiana, and to a lesser extent in Mississippi and Texas. The storm resulted in widespread power outages, significant damage primarily to distribution infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy's electric facilities in areas with damage from Hurricane Delta are currently estimated to be in the range of $250 million to $300 million, including $180 million to $205 million at Entergy Louisiana, $30 million to $35 million at Entergy Mississippi, and $40 million to $50 million at Entergy Texas. Entergy is considering all available avenues to recover storm-related costs from Hurricane Delta, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to portions of Entergy's service area in Louisiana, including New Orleans. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Entergy is still assessing and developing an estimate of the total restoration costs for the repair and/or replacement of the infrastructure damaged by Hurricane Zeta. Entergy is considering all available avenues to recover storm-related costs from Hurricane Zeta, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.


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Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Results of Operations

Third Quarter 2020 Compared to Third Quarter 2019

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the third quarter 2020 to the third quarter 2019 showing how much the line item increased or (decreased) in comparison to the prior period:

Utility
Entergy
Wholesale
Commodities

Parent &
Other (a)

Entergy
(In Thousands)
2019 Net Income (Loss) Attributable to Entergy Corporation$578,291 ($141,048)($72,003)$365,240 
Operating revenues(151,036)(85,992)21 (237,007)
Fuel, fuel-related expenses, and gas purchased for resale(163,986)(11,290)5 (175,271)
Purchased power(62,312)10,902 (5)(51,415)
Other regulatory charges (credits)(34,161)— — (34,161)
Other operation and maintenance(26,190)(22,648)(5,521)(54,359)
Asset write-offs, impairments, and related charges— (193,625)— (193,625)
Taxes other than income taxes8,402 (2,795)87 5,694 
Depreciation and amortization39,576 (17,136)(81)22,359 
Other income (deductions)(31,142)52,757 6,873 28,488 
Interest expense14,815 (642)(4,081)10,092 
Other expenses(3,865)(10,451)— (14,316)
Income taxes71,924 43,176 5,143 120,243 
Preferred dividend requirements of subsidiaries361 — — 361 
2020 Net Income (Loss) Attributable to Entergy Corporation$551,549 $30,226 ($60,656)$521,119 

(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 third quarter 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.
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Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$2,840 
Fuel, rider, and other revenues that do not significantly affect net income(237)
Volume/weather(81)
Return of unprotected excess accumulated deferred income taxes to customers75 
Retail electric price92 
2020 operating revenues$2,689 

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to decreased commercial and industrial usage as a result of the COVID-19 pandemic and the effects of Hurricane Laura in addition to the effect of less favorable weather on residential sales, partially offset by an increase in residential usage as a result of the COVID-19 pandemic. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. Entergy continues to expect a decline in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” above for discussion of the COVID-19 pandemic. See “Hurricane Laura” above for discussion of Hurricane Laura.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In third quarter 2020, $16 million was returned to customers through reductions in operating revenues as compared to $91 million in third quarter 2019. There is no effect on net income as the reductions in operating revenues were offset by reductions 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:

•an interim increase in Entergy Louisiana’s formula rate plan revenues effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station and increases in formula rate plan revenues effective September 2019 and September 2020;
•an increase in Entergy Mississippi’s formula rate plan rates effective with the first billing cycle of April 2020 and an interim capacity rate adjustment to the formula rate plan to recover non-fuel related costs of acquiring and operating the Choctaw Generating Station;
•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of January 2020;
•the implementation of a vegetation management rider at Entergy Mississippi effective with the April 2020
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billing cycle; and
•an increase in Entergy Texas’s transmission cost recovery factor rider in January 2020.

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

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $300 million for the third quarter 2019 to $214 million for the third quarter 2020 primarily due to the shutdown of Indian Point 2 in April 2020.

Following are key performance measures for Entergy Wholesale Commodities for the third quarters 2020 and 2019:
20202019
Owned capacity (MW) (a)2,2463,274
GWh billed4,3326,847
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor83%98%
GWh billed3,9436,210
Average energy price ($/MWh)$39.51$37.29
Average capacity price ($/kW-month)$3.62$4.50
Refueling outage days:
Palisades32—

(a)The reduction in owned capacity is due to the shutdown of the 1,028 MW Indian Point 2 plant in April 2020.

Other Income Statement Items

Utility

Other operation and maintenance expenses decreased from $658 million for the third quarter 2019 to $632 million for the third quarter 2020 primarily due to:

•a decrease of $9 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services;
•a decrease of $9 million in loss provisions; and
•a decrease of $7 million in non-nuclear generation expenses due to lower long-term service agreement expenses and a lower scope of work performed in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic.

The decrease was partially offset by an increase of $5 million in compensation and benefits costs primarily due to an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.

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Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station and the Choctaw Generating Station.

Other income decreased primarily due to changes in decommissioning trust fund activity and a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the Lake Charles Power Station project.

Interest expense increased primarily due to:

•the issuances by Entergy Louisiana of $350 million of 2.90% Series mortgage bonds and $300 million of 4.20% Series mortgage bonds, each in March 2020;
•the issuance by Entergy Texas of $175 million of 3.55% Series mortgage bonds in March 2020; and
•the issuances by Entergy Mississippi of $135 million of 3.85% Series mortgage bonds in November 2019 and $170 million of 3.50% Series mortgage bonds in May 2020.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $136 million for the third quarter 2019 to $114 million for the third quarter 2020 primarily due to the absence of expenses from Indian Point 2 after it was shut down in April 2020.

Asset write-offs, impairments, and related charges for the third quarter 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet. See Note 14 to the financial statements in the Form 10-K for a discussion of the sale of the Pilgrim plant and for a discussion of impairment of long-lived assets.

Depreciation and amortization expenses decreased primarily due to the absence of depreciation expense from the Indian Point 2 plant, after it was shut down in April 2020.

Other income increased primarily due to higher gains on decommissioning trust fund investments in third quarter 2020 as compared to third quarter 2019 and settlement charges recognized in third quarter 2019 on previously deferred pension plan losses. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 6 to the financial statements herein and Note 11 to the financial statements in the Form 10-K for a discussion of retirement plans.

Other expenses decreased primarily due to the absence of decommissioning expense from the Pilgrim plant, after it was sold in August 2019. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.

Income Taxes

The effective income tax rate was 22.1% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, offset by the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items. See Note 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 7.3% for the third quarter 2019. The difference in the effective income tax rate for the third quarter 2019 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,
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partially offset by state income taxes. See Note 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.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019 showing how much the line item increased or (decreased) in comparison to the prior period:

Utility
Entergy
Wholesale
Commodities

Parent &
Other (a)

Entergy
(In Thousands)
2019 Net Income (Loss) Attributable to Entergy Corporation$1,140,066 ($70,445)($213,420)$856,201 
Operating revenues(395,765)(277,128)60 (672,833)
Fuel, fuel-related expenses, and gas purchased for resale(357,583)(24,950)17 (382,516)
Purchased power(308,721)530 (17)(308,208)
Other regulatory charges (credits)(23,608)— — (23,608)
Other operation and maintenance(107,329)(127,708)(5,899)(240,936)
Asset write-offs, impairments, and related charges— (272,151)— (272,151)
Taxes other than income taxes14,085 (1,321)(115)12,649 
Depreciation and amortization137,981 (32,914)— 105,067 
Other income (deductions)(43,127)(169,527)13,978 (198,676)
Interest expense47,565 (6,549)(3,967)37,049 
Other expenses(1,852)(36,405)— (38,257)
Income taxes83,100 (19,514)30,350 93,936 
Preferred dividend requirements of subsidiaries1,301 — — 1,301 
2020 Net Income (Loss) Attributable to Entergy Corporation$1,216,235 $3,882 ($219,751)$1,000,366 

(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.

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Results of operations for the nine months ended September 30, 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019 and impairment charges of $98 million ($77 million net-of-tax) due to costs being charged directly 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 exit the Entergy Wholesale Commodities’ merchant power business. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet.

Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$7,393 
Fuel, rider, and other revenues that do not significantly affect net income(635)
Volume/weather(144)
Return of unprotected excess accumulated deferred income taxes to customers157 
Retail electric price226 
2020 operating revenues$6,997 

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to decreased commercial and industrial usage as a result of the COVID-19 pandemic and the effects of Hurricane Laura in addition to the effect of less favorable weather on residential sales, partially offset by an increase in residential usage as a result of the COVID-19 pandemic. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. Entergy continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” above for discussion of the COVID-19 pandemic. See “Hurricane Laura” above for discussion of Hurricane Laura.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In the nine months ended September 30, 2020, $55 million was returned to customers through reductions in operating revenues as compared to $212 million in the nine months ended September 30, 2019. There is no effect on net income as the reductions in operating revenues were offset by reductions 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.     

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The retail electric price variance is primarily due to:

•interim increases in Entergy Louisiana’s formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for the J. Wayne Leonard Power Station (formerly St. Charles Power Station) and effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station and increases in formula rate plan revenues effective September 2019 and September 2020;
•increases in Entergy Mississippi’s formula rate plan rates effective with the first billing cycles of July 2019 and April 2020 and an interim capacity rate adjustment to the formula rate plan to recover non-fuel related costs of acquiring and operating the Choctaw Generating Station;
•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of January 2020;
•the implementation of a vegetation management rider at Entergy Mississippi effective with the April 2020 billing cycle; and
•an increase in Entergy Texas’s transmission cost recovery factor rider in January 2020.

The increase was partially offset by the effects of Entergy New Orleans’s rate reduction implemented with April 2020 bills that was effective August 2019 in accordance with the City Council resolution and related agreement in principle reached in the 2018 base rate case.

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

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $1,024 million for the nine months ended September 30, 2019 to $747 million for the nine months ended September 30, 2020 primarily due to the shutdown of Pilgrim in May 2019, the shutdown of Indian Point 2 in April 2020, and lower realized wholesale energy and capacity prices. The decrease was partially offset by higher volume in the remaining Entergy Wholesale Commodities nuclear fleet resulting from fewer outage days and a larger exercise of resupply options provided for in purchase power agreements where Entergy Wholesale Commodities may elect to supply power from another source when plants are not running.

Following are key performance measures for Entergy Wholesale Commodities for the nine months ended September 30, 2020 and 2019:
20202019
Owned capacity (MW) (a) 2,2463,274
GWh billed16,04721,308
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor94%91%
GWh billed14,78219,602
Average energy price ($/MWh)$41.61$40.85
Average capacity price ($/kW-month)$2.06$4.83
Refueling outage days:
Indian Point 3—29
Palisades32—

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(a)The reduction in owned capacity is due to the shutdown of the 1,028 MW Indian Point 2 plant in April 2020.

Other Income Statement Items

Utility

Other operation and maintenance expenses decreased from $1,894 million for the nine months ended September 30, 2019 to $1,787 million for the nine months ended September 30, 2020 primarily due to:

•a decrease of $48 million in non-nuclear generation expenses due to a lower scope of work performed during plant outages in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic, and lower long-term service agreement expenses;
•a decrease of $41 million in nuclear generation expenses primarily due to a lower scope of work performed in 2020 as compared to 2019 and lower nuclear labor costs, including contract labor, in part as a result of the COVID-19 pandemic;
•a decrease of $22 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services;
•higher nuclear insurance refunds of $18 million; and
•a decrease of $10 million in loss provisions.

The decrease was partially offset by:

•an increase of $19 million in compensation and benefits costs primarily due to an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and
•an increase of $9 million in storm damage provisions at Entergy Mississippi. See Note 2 to the financial statements in the Form 10-K for discussion of storm recovery.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the J. Wayne Leonard Power Station (formerly St. Charles Power Station), the Lake Charles Power Station, and the Choctaw Generating Station, and new depreciation rates at Entergy Mississippi, as approved by the MPSC.

Other income decreased primarily due to:

•changes in decommissioning trust fund activity;
•a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the J. Wayne Leonard Power Station (formerly St. Charles Power Station) project and the Lake Charles Power Station project, partially offset by construction work in progress in 2020 related to the Montgomery County Power Station project; and
•an increase in net periodic pension and other postretirement benefits non-service pension costs as a result of a decrease in the discount rate used to value the benefits liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.

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Interest expense increased primarily due to:

•the issuances by Entergy Texas of $300 million in September 2019 and $175 million in March 2020 of 3.55% Series mortgage bonds;
•the issuances by Entergy Louisiana of $300 million of 4.20% Series mortgage bonds and $350 million of 2.90% Series mortgage bonds, each in March 2020, and $525 million of 4.20% Series mortgage bonds in March 2019;
•the issuances by Entergy Arkansas of $350 million of 4.20% Series mortgage bonds in March 2019 and $100 million of 4.0% Series mortgage bonds in March 2020; and
•the issuances by Entergy Mississippi of $135 million of 3.85% Series mortgage bonds in November 2019 and $170 million of 3.50% Series mortgage bonds in May 2020.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $513 million for the nine months ended September 30, 2019 to $385 million for the nine months ended September 30, 2020 primarily due to:

•a decrease of $112 million resulting from the absence of expenses from the Pilgrim plant after it was shut down in May 2019 and the Indian Point 2 plant after it was shut down in April 2020; and
•a decrease of $17 million in severance and retention expenses. Severance and retention expenses were incurred in 2020 and 2019 due to management’s strategy to exit the Entergy Wholesale Commodities merchant power business. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses resulting from management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.

Asset write-offs, impairments, and related charges for the nine months ended September 30, 2020 include impairment charges of $16 million ($13 million net-of-tax) primarily as a result of expenditures for capital assets. Asset write-offs, impairments, and related charges for the nine months ended September 30, 2019 include impairment charges of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019 and impairment charges of $98 million ($77 million net-of-tax) related to nuclear refueling outage spending and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair 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 exit the Entergy Wholesale Commodities merchant power business. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet. See Note 14 to the financial statements in the Form 10-K for a discussion of the sale of the Pilgrim plant and for a discussion of impairment of long-lived assets.

Depreciation and amortization expenses decreased primarily due to the absence of depreciation expense from the Indian Point 2 plant, after it was shut down in April 2020.

Other income decreased primarily due to lower gains on decommissioning trust fund investments in the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

Other expenses decreased primarily due to the absence of decommissioning expense from the Pilgrim plant, after it was sold in August 2019. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.
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Income Taxes

The effective income tax rate was 14.2% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 10 to the financial statements herein for discussion of the IRS settlement and the income tax deductions for stock-based compensation. See Note 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 7.8% for the nine months ended September 30, 2019. The difference in the effective income tax rate for the nine months ended September 30, 2019 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes and the tax effects of the disposition of Vermont Yankee. See Note 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 3 to the financial statements in the Form 10-K for a discussion of the tax effects of the Vermont Yankee disposition.

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, 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of 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 shut down and sell all remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.  Following are updates to that discussion.

Shutdown and Sale of Pilgrim

As discussed in the Form 10-K, Pilgrim ceased operations in May 2019. On August 22, 2019, the NRC approved the transfer of Pilgrim’s facility licenses to Holtec International. At that time, hearing requests filed by the Commonwealth of Massachusetts and Pilgrim Watch challenging Holtec’s financial qualifications and the sufficiency of the NRC’s review of the associated environmental impacts of the license transfer were pending with the NRC Commissioners. The NRC approval order included a condition acknowledging the NRC’s longstanding authority to modify, condition, or rescind the license transfer order as a result of any hearing that may be conducted. On August 26, 2019, as permitted by the August 22 order, Entergy and Holtec closed the transaction. On September 25, 2019, Massachusetts filed a petition with the U.S. Court of Appeals for the District of Columbia Circuit, asking the court to vacate the NRC’s August 22 license transfer approval order and related approvals. On November 22, 2019, Entergy and Holtec filed a motion to dismiss Massachusetts’s petition; the NRC also filed a motion to dismiss on the same date. On January 22, 2020, Massachusetts filed a second petition with the D.C. Circuit asking the court to review the NRC’s December 17 order denying its stay motion. On June 16, 2020, Holtec
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and Massachusetts reached a settlement to resolve issues related to the Pilgrim transaction. Pursuant to the settlement agreement, Massachusetts withdrew its hearing request pending before the NRC and withdrew both of its petitions for review before the D.C. Circuit, thereby terminating Massachusetts’s pending legal challenges to the Pilgrim transfer.

Planned Shutdown and Sale of Indian Point 2 and Indian Point 3

As discussed in the Form 10-K, in April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 has been shut down and defueled, to a Holtec subsidiary for decommissioning. The sale will include the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. Subject to the conditions discussed in the Form 10-K, the transaction is targeted to close in May 2021, following the defueling of Indian Point 3. The NRC publicly stated it expects to complete its technical and financial assurance review of the license transfer application by the end of 2020. As consideration for the transfer to Holtec of its interest in Indian Point, Entergy will receive nominal cash consideration. The terms of the transaction do not require a minimum level of funding in the nuclear decommissioning trusts as a condition to closing. The Indian Point transaction is expected to result in a loss based on the difference between Entergy’s adjusted net investment in the subsidiaries at closing and the sale price net of any agreed adjustments. As of September 30, 2020, Entergy’s adjusted net investment in the Indian Point units was $210 million. The primary variables in the ultimate loss that Entergy will incur are the values of the nuclear decommissioning trusts and the asset retirement obligations at closing, the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing. Indian Point 2 permanently ceased operations on April 30, 2020.

Planned Shutdown and Sale of Palisades

As discussed in the Form 10-K, in July 2018, Entergy entered into a purchase and sale agreement to sell 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site, for $1,000 (subject to adjustment for net liabilities and other amounts). The sale will include the transfer of the nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. In February 2020 the parties signed an amendment to the purchase and sale agreement to remove the closing condition that the nuclear decommissioning trust fund must have a specified amount and Entergy agreed to contribute $20 million to the nuclear decommissioning trust fund at closing, among other amendments. Subject to the conditions discussed in the Form 10-K, the transaction is expected to close by the end of 2022. As of September 30, 2020, Entergy’s adjusted net investment in Palisades was $75 million. The primary variables in the ultimate loss or gain that Entergy will incur on the transaction are the values of the nuclear decommissioning trust and the asset retirement obligations at closing, the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing. Palisades completed its final refueling outage in October 2020.

Costs Associated with Entergy Wholesale Commodities Strategic Transactions

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $70 million in 2020, of which $57 million has been incurred as of September 30, 2020, and a total of approximately $55 million from 2021 through 2022. In addition, Entergy Wholesale Commodities incurred impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets of $4 million for the three months ended September 30, 2020 and $16 million for the nine months ended September 30, 2020. 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 exit the Entergy Wholesale Commodities merchant power business. 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.
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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.

Entergy has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” above for discussion of the COVID-19 pandemic. Additional discussion of Entergy’s liquidity and capital resources follows.

Capital Structure and Resources

Entergy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy as of September 30, 2020 is primarily due to the net issuance of debt in 2020.
September 30,
2020		December 31,
2019
Debt to capital66.7 %65.5 %
Effect of excluding securitization bonds(0.2 %)(0.4 %)
Debt to capital, excluding securitization bonds (a)66.5 %65.1 %
Effect of subtracting cash(1.3 %)(0.5 %)
Net debt to net capital, excluding securitization bonds (a)65.2 %64.6 %

(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, finance 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 September 2024.  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 nine months ended September 30, 2020 was 2.50% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2020:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$150$6$3,344
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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 Registrant Subsidiaries (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 Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of September 30, 2020, Entergy Corporation had approximately $1,398 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2020 was 1.66%.

Certain of the Utility operating companies have a total of $373 million in storm reserve escrow accounts at September 30, 2020.

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 2020 through 2022. Following are updates to that discussion.

Preliminary Capital Investment Plan Estimate for 2021-2023

Entergy is developing its capital investment plan for 2021 through 2023 and currently anticipates that the Utility will make approximately $11.9 billion in capital investments during that period and that Entergy Wholesale Commodities will make approximately $20 million in capital investments, not including nuclear fuel, during that period. The preliminary Utility estimate includes specific investments such as the Montgomery County Power Station, Sunflower Solar Facility, Searcy Solar Facility, Walnut Bend Solar Facility, and Liberty County Solar Facility; 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 Entergy’s nuclear fleet; software and security; and other investments. The preliminary Entergy Wholesale Commodities estimate includes amounts associated with specific investments, such as 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.

Lake Charles Power Station

As discussed in the Form 10-K, the LPSC issued an order in July 2017 approving certification that the public necessity and convenience would be served by the construction of the Lake Charles Power Station. The plant commenced commercial operation in March 2020.


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New Orleans Power Station

As discussed in the Form 10-K, in June 2019, a state court judge in New Orleans affirmed the City Council’s approval of the New Orleans Power Station and dismissed the petition for judicial review of that decision that had been filed in April 2018. The petitioners have filed an appeal of that ruling. Also in June 2019, with regard to the lawsuit challenging the City Council’s decision on the basis of a violation of the open meetings law, the same state court judge in New Orleans ruled that there was a violation of the open meetings law at the February 2018 meeting of the City Council’s Utility Committee at which that Committee considered the New Orleans Power Station approval, and further ruled that, although there was no violation of the open meetings law at the March 2018 City Council meeting at which the New Orleans Power Station was approved, both the approval of the Utility Committee and the approval of the City Council were void. The City Council and Entergy New Orleans each filed a suspensive appeal of the open meetings law ruling. A suspensive appeal suspends the effect of the judgment in the open meetings law proceeding while the appeal is being taken. The petitioners sought in the state appellate court, and then at the Louisiana Supreme Court, to terminate the suspension of the effect of the judgment, but both courts declined to do so. Oral argument in both cases was heard in January 2020. In February 2020 the state appellate court reversed the lower court’s ruling that the City Council’s approval of the New Orleans Power Station was void due to a violation of the open meetings law at the City Council’s Utility Committee meeting in February 2018.  The state appellate court ruled that there was no violation of the open meetings law at the City Council meeting in March 2018 and that the lower court erred in voiding the City Council resolution approving the New Orleans Power Station.  In March 2020 the appellees in that proceeding filed a writ application with the Louisiana Supreme Court seeking review of the appellate court’s decision and several New Orleans-based organizations filed an amicus brief in support of the appellees’ writ application. Entergy New Orleans and the City Council each filed an opposition to the writ application in June 2020, and the City Council also filed its own writ application seeking reversal of the appellate court’s holding that there was a violation of the open meetings law at the February 2018 City Council’s Utility Committee meeting. In its writ application the City Council requested that the Louisiana Supreme Court deny the appellees’ writ application, and grant the City Council’s writ application only if the Supreme Court grants the appellees’ writ application. In April 2020 the state appellate court affirmed the district court’s judicial review decision that affirmed the City Council’s approval of the New Orleans Power Station as in the public interest. In June 2020 appellants in that case filed a writ application with the Louisiana Supreme Court seeking review and reversal of that appellate court ruling. In July 2020 the City Council and Entergy New Orleans each filed an opposition to appellants’ writ application in the judicial review case. Commercial operation of the plant commenced in May 2020. In accordance with the City Council resolution issued in the 2018 base rate case proceeding, Entergy New Orleans has been deferring the New Orleans Power Station non-fuel costs pending the conclusion of the appellate proceedings. In October 2020 the Louisiana Supreme Court denied all writ applications relating to the New Orleans Power Station. With those denials, Entergy New Orleans expects to begin recovering New Orleans Power Station costs in rates as early as November 2020.

Sunflower Solar Facility

In November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi.  The estimated base purchase price is approximately $138.4 million.  The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 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.  The project will be built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met.  In December 2018, Entergy Mississippi filed a joint petition with Sunflower Solar Project at the MPSC for Sunflower Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility.  Entergy Mississippi has 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
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Entergy Mississippi, including the annual ownership costs of the Sunflower Solar Facility. In December 2019 the MPSC approved Entergy Mississippi’s proposed revisions to its formula rate plan to provide for an interim capacity rate adjustment mechanism. Recovery through the interim capacity rate adjustment requires MPSC approval for each new resource. In August 2019 consultants retained by the Mississippi Public Utilities Staff filed a report expressing concerns regarding the project economics. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised by the consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. A hearing before the MPSC was held in March 2020. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar Facility and its recovery through the interim capacity rate adjustment mechanism, subject to certain conditions including: (i) that Entergy Mississippi pursue a partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. Closing is targeted to occur by the end of 2021.

Searcy Solar Facility

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the Searcy Solar Facility was in the public interest. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest, but declined to approve Entergy Arkansas’s preferred cost recovery rider mechanism, finding instead, based on the particular facts and circumstances presented, that the formula rate plan rider was a sufficient recovery mechanism for this resource.

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 October 2020 meeting, the Board declared a dividend of $0.95 per share, an increase from the previous $0.93 quarterly dividend per share that Entergy has paid since the third quarter 2019.

Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Millions)
Cash and cash equivalents at beginning of period$426 $481 
Cash flow provided by (used in):  
Operating activities2,370 2,118 
Investing activities(3,256)(3,025)
Financing activities1,700 1,382 
Net increase in cash and cash equivalents814 475 
Cash and cash equivalents at end of period$1,240 $956 


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Operating Activities

Net cash flow provided by operating activities increased $252 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the decrease in the return of unprotected excess accumulated deferred income taxes to Utility customers. See Note 2 to the financial statements in the Form 10-K for a discussion of the regulatory activity regarding the Tax Cuts and Jobs Act;
•a decrease of $125 million in severance and retention payments in 2020 as compared to prior year. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” above for a discussion of management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business;
•a decrease of $58 million in spending on nuclear refueling outages;
•an increase of $36 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and
•an increase of $25 million of nuclear insurance refunds.

The increase was partially offset by:

•an increase of $66 million in pension contributions in 2020 as compared to the same period in 2019. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding;
•the timing of collections of receivables from customers, in part due to the COVID-19 pandemic;
•the effect of less favorable weather on billed Utility sales in 2020; and
•an increase of $32 million in incentive-based compensation payments in 2020.

Investing Activities

Net cash flow used in investing activities increased $231 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•an increase of $132 million in construction expenditures in the Utility business, as discussed below;
•an increase of $122 million in nuclear fuel purchases due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle;
•an increase of $40 million primarily due to changes in collateral posted to provide credit support to secure obligations under agreements to sell power produced by Entergy Wholesale Commodities’ power plants; and
•$25 million in plant upgrades for the Choctaw Generating Station in March 2020. See Note 14 to the financial statements in the Form 10-K for further discussion of the Choctaw Generating Station purchase.

The increase was partially offset by:

•an increase of $65 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and
•an increase of $45 million in net receipts from storm reserve escrow accounts.

The increase in construction expenditures in the Utility business is primarily due to an increase of $211 million in storm spending in 2020, including spending on Hurricane Laura restoration efforts, and an increase of
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$156 million largely resulting from investment in the infrastructure of the distribution system, including increased spending on advanced metering infrastructure. The increase was partially offset by a decrease of $206 million in non-nuclear generation construction expenditures primarily due to higher spending in 2019 on the Montgomery County Power Station, Lake Charles Power Station, and J. Wayne Leonard Power Station (formerly St. Charles Power Station) projects and a decrease of $34 million in transmission construction expenditures primarily due to the timing of work performed in 2020 as compared to the same period in 2019.

Financing Activities

Net cash flow provided by financing activities increased $318 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•long-term debt activity providing approximately $2,784 million of cash in 2020 compared to providing approximately $1,274 million of cash in 2019; and
•the repurchase in first quarter 2019 of $50 million of Class A mandatorily redeemable preferred membership units in Entergy Holdings Company LLC, a wholly-owned Entergy subsidiary, that were held by a third party.

The increase was partially offset by:

•proceeds of $608 million from the issuance of common stock in May 2019 as a result of the settlement of equity forwards. See Note 7 to the financial statements in the Form 10-K for discussion of the equity forward sale agreements;
•an increase of $523 million in net repayments of commercial paper in 2020 compared to 2019;
•a decrease of $48 million in treasury stock issuances in 2020 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2019 to satisfy stock option exercises;
•the issuance of $35 million aggregate liquidation value 5.375% Series A preferred stock in September 2019 by Entergy Texas; and
•an increase of $32 million in common stock dividends paid as a result of an increase in the number of shares outstanding and an increase in the dividend per share in 2020 compared to 2019.

For details of Entergy’s commercial paper program 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.

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.

Federal Regulation

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

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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 use a combination of financial contracts, including swaps, collars, and options, to manage forward commodity price risk. 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 September 30, 2020 (2020 represents the remainder of the year):

Entergy Wholesale Commodities Nuclear Portfolio
202020212022
Energy
Percent of planned generation under contract (a):
Unit-contingent (b)97%98%99%
Planned generation (TWh) (c) (d)3.59.62.8
Average revenue per MWh on contracted volumes:
Expected based on market prices as of September 30, 2020$36.8$54.5$47.1
Capacity
Percent of capacity sold forward (e):
Bundled capacity and energy contracts (f)42%68%97%
Capacity contracts (g)37%15%—%
Total79%83%97%
Planned net MW in operation (average) (d)1,8521,158338
Average revenue under contract per kW per month (applies to capacity contracts only)$1.9$0.2$—
Total Energy and Capacity Revenues (h)
Expected sold and market total revenue per MWh$40.6$54.1$46.8
Sensitivity: -/+ $10 per MWh market price change$40.5-$40.7$53.9-$54.3$46.7-$47.0

(a)Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts, or options that mitigate price uncertainty. Positions that are not classified as hedges are netted in the planned generation under contract.
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(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)Amount of output expected to be generated by Entergy Wholesale Commodities nuclear resources considering plant operating characteristics and outage schedules.
(d)Assumes the planned shutdown of Indian Point 3 on April 30, 2021 and planned shutdown of Palisades on May 31, 2022. For a discussion regarding the planned shutdown of the Indian Point 3 and Palisades plants, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” above.
(e)Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.
(f)A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.
(g)A contract for the sale of an installed capacity product in a regional market.
(h)Includes assumptions on converting a portion of the portfolio to contracted with fixed price and excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

As of September 30, 2020, a positive $10 per MWh change and a negative $10 per MWh change would each have an insignificant corresponding effect on pre-tax income for the remainder of 2020. 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 September 30, 2019 market conditions, planned generation volumes, and hedged positions, would have had a corresponding effect on pre-tax income of $2 million for the remainder of 2019. A negative $10 per MWh change in the annual average energy price in the markets based on September 30, 2019 market conditions, planned generation volumes, and hedged positions, would have had a corresponding effect on pre-tax income of ($2) million for the remainder of 2019.

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 guarantee.  Cash and letters of credit are also acceptable forms of credit support. At September 30, 2020, based on power prices at that time, Entergy had liquidity exposure of $58 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $20 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 September 30, 2020, Entergy would have been required to provide approximately $30 million of additional cash or letters of credit under some of the agreements. As of September 30, 2020, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by $40 million for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of September 30, 2020, 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.


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NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs. The nuclear generating plants owned and operated by Entergy’s Utility and Entergy Wholesale Commodities businesses are currently in Column 1. Grand Gulf, however, is expected to be placed in Column 2 by the NRC based on the incidence of unplanned plant scrams during the third quarter 2020.

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, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies. Following are updates to the discussion in the Form 10-K.

Qualified Pension and Other Postretirement Benefits

As discussed in the Form 10-K, Entergy sponsors qualified, defined benefit pension plans that cover substantially all employees, including cash balance plans and final average pay plans. Entergy’s reported costs of providing these benefits, as described in Note 11 to the financial statements in the Form 10-K, are affected by numerous factors. Key actuarial assumptions utilized in determining qualified pension and other postretirement health care and life insurance costs include the expected long-term rate of return on plan assets. For 2020, Entergy assumed a long-term rate of return on its qualified pension plan assets of 7.00%. Through September 30, 2020, Entergy experienced a 5.7% positive return on its qualified pension plan assets.
As described more fully in the Form 10-K, in accordance with pension accounting standards, Entergy utilizes a number of accounting mechanisms that reduce the volatility of reported pension costs. Differences between actuarial assumptions and actual plan results are deferred and are amortized into expense when the accumulated differences exceed 10% of the greater of the projected benefit obligation or the market-related value of plan assets. The excess is amortized over the average remaining service period of active employees.
Minimum required funding calculations as determined under Pension Protection Act guidance are performed annually as of January 1 of each year and are based on measurements of the assets and funding liabilities as measured at that date, and Entergy’s expected contributions for 2020 are reported in Note 6 to the financial statements herein. Any excess of the funding liability over the calculated fair market value of assets results in a funding shortfall that, under the Pension Protection Act, must be funded over a seven-year rolling period. The Pension Protection Act also imposes certain plan limitations if the funded percentage, which is based on calculated fair market values of assets divided by funding liabilities, does not meet specified thresholds. For funding purposes, asset gains and losses are smoothed in to the calculated fair market value of assets. The funding liability is based upon a weighted average 24-month corporate bond rate published by the U.S. Treasury which is generally subject to a corridor of the 25-year average of prior segment rates. Periodic changes in asset returns and interest rates can affect funding shortfalls and future cash contributions.


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As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, Entergy now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $17.2 million.

Taxation and Uncertain Tax Positions

As described more fully in the Form 10-K, management exercises significant judgment in evaluating the potential tax effects of Entergy’s operations, transactions, and other events. Entergy accounts for uncertain tax positions using a recognition model under a two-step approach with a more likely than not recognition threshold and a measurement approach based on the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income tax expense and tax positions recorded could be significantly affected by events such as additional transactions contemplated or consummated by Entergy as well as audits by taxing authorities. Included in the current IRS examination of Entergy’s 2015 tax returns is the tax effect of the October 2015 combination of two Entergy utility companies, Entergy Gulf States Louisiana and Entergy Louisiana. Entergy Louisiana maintained a carryover tax basis in the assets received and the tax consequences provided for an increase in tax basis as well. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. As discussed in Note 3 to the financial statements in the Form 10-K, Entergy expects the IRS to complete its examination of the 2014 and 2015 tax years before the end of 2020, the result of which could affect the amount of the permanent difference and uncertain tax position.

In addition, as discussed in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein, in 2015, System Energy and Entergy Louisiana adopted a new method of accounting for income tax return purposes in which nuclear decommissioning liabilities are treated as production costs of electricity includable in cost of goods sold. The new method resulted in a reduction of taxable income of $1.2 billion for System Energy and $2.2 billion for Entergy Louisiana in 2015. In the third quarter 2020 the IRS issued Notices of Proposed Adjustment concerning this uncertain tax position allowing System Energy to include $102 million of its decommissioning liability in cost of goods sold and Entergy Louisiana to include $221 million of its decommissioning liability in cost of goods sold. The Notices of Proposed Adjustment will not be appealed.

As a result of System Energy being allowed to include part of its decommissioning liability in cost of goods sold, System Energy and Entergy recorded a deferred tax liability of $26 million. System Energy also recorded federal and state taxes payable of $402 million; on a consolidated basis, however, Entergy utilized tax loss carryovers to offset the federal taxable income adjustment and accordingly did not record federal taxes payable as a result of the outcome of this uncertain tax position.

As a result of Entergy Louisiana being allowed to include part of its decommissioning liability in cost of goods sold, Entergy Louisiana and Entergy recorded a deferred tax liability of $60 million. Both Entergy Louisiana and Entergy utilized tax loss carryovers to offset the taxable income adjustment and accordingly did not record taxes payable as a result of the outcome of this uncertain tax position.

The partial disallowance of the uncertain tax position to include the decommissioning liability in cost of goods sold resulted in a $1.5 billion decrease in the balance of unrecognized tax benefits related to federal and state taxes for Entergy. Additionally, both System Energy and Entergy Louisiana recorded a reduction to their balances of unrecognized tax benefits for federal and state taxes of $461 million and $1.1 billion, respectively.

The tax treatment of Entergy Louisiana’s accrued regulatory liabilities associated with the Vidalia purchased power agreement and business combination guaranteed customer credits, which are discussed in Note 2 to the financial statements in the Form 10-K, has been resolved in a manner that results in a $190 million increase to previously reported taxable income. Entergy Louisiana and Entergy utilized tax loss carryovers to offset the taxable income adjustment, however, which allowed both Entergy Louisiana and Entergy to reduce their balances of federal and state unrecognized tax benefits by $74 million.

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New Accounting Pronouncements

See Note 1 to the financial statements in the Form 10-K for discussion of new accounting pronouncements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands, Except Share Data)
OPERATING REVENUES
Electric$2,666,805 $2,812,934 $6,907,999 $7,279,683 
Natural gas22,357 27,269 88,829 112,916 
Competitive businesses214,406 300,372 746,706 1,023,768 
TOTAL2,903,568 3,140,575 7,743,534 8,416,367 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale421,668 596,939 1,160,076 1,542,592 
Purchased power264,924 316,339 693,499 1,001,707 
Nuclear refueling outage expenses44,384 52,044 139,496 153,447 
Other operation and maintenance751,337 805,696 2,189,681 2,430,617 
Asset write-offs, impairments, and related charges4,461 198,086 16,332 288,483 
Decommissioning95,155 101,811 284,251 308,557 
Taxes other than income taxes171,425 165,731 500,364 487,715 
Depreciation and amortization401,578 379,219 1,205,057 1,099,990 
Other regulatory charges (credits)(29,380)4,781 (62,306)(38,698)
TOTAL2,125,552 2,620,646 6,126,450 7,274,410 
OPERATING INCOME 778,016 519,929 1,617,084 1,141,957 
OTHER INCOME
Allowance for equity funds used during construction24,915 33,161 89,238 108,546 
Interest and investment income 127,857 82,295 195,826 406,663 
Miscellaneous - net(58,914)(50,086)(129,145)(160,614)
TOTAL93,858 65,370 155,919 354,595 
INTEREST EXPENSE
Interest expense207,811 201,412 630,199 603,517 
Allowance for borrowed funds used during construction(11,080)(14,773)(38,667)(49,034)
TOTAL196,731 186,639 591,532 554,483 
INCOME BEFORE INCOME TAXES675,143 398,660 1,181,471 942,069 
Income taxes149,444 29,201 167,366 73,430 
CONSOLIDATED NET INCOME 525,699 369,459 1,014,105 868,639 
Preferred dividend requirements of subsidiaries4,580 4,219 13,739 12,438 
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
$521,119 $365,240 $1,000,366 $856,201 
Earnings per average common share:
Basic$2.60 $1.84 $5.00 $4.42 
Diluted$2.59 $1.82 $4.98 $4.38 
Basic average number of common shares outstanding200,220,018 198,932,387 200,063,256 193,876,557 
Diluted average number of common shares outstanding201,115,768 200,492,935 200,957,465 195,685,851 
See Notes to Financial Statements.


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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)
Net Income $525,699 $369,459 $1,014,105 $868,639 
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of ($4,408), ($5,343), ($16,945), and $14,547)
(16,558)(20,103)(63,674)62,453 
Pension and other postretirement liabilities (net of tax expense of $4,697, $6,760, $24,487, and $13,086)
17,437 25,464 88,560 48,510 
Net unrealized investment gain (net of tax expense (benefit) of ($1,513), $1,303, $18,042, and $17,472)
(2,695)5,271 31,614 33,244 
Other comprehensive income (loss)(1,816)10,632 56,500 144,207 
Comprehensive Income 523,883 380,091 1,070,605 1,012,846 
Preferred dividend requirements of subsidiaries4,580 4,219 13,739 12,438 
Comprehensive Income Attributable to Entergy Corporation$519,303 $375,872 $1,056,866 $1,000,408 
See Notes to Financial Statements.
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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Consolidated net income $1,014,105 $868,639 
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization1,694,904 1,634,677 
Deferred income taxes, investment tax credits, and non-current taxes accrued320,726 373,723 
Asset write-offs, impairments, and related charges16,117 225,175 
Changes in working capital:
Receivables(200,990)(231,005)
Fuel inventory(608)(14,399)
Accounts payable174,083 (175,246)
Taxes accrued206,769 (2,420)
Interest accrued10,866 (2,314)
Deferred fuel costs(48,162)90,319 
Other working capital accounts(114,492)(19,232)
Changes in provisions for estimated losses(38,029)14,114 
Changes in other regulatory assets(130,533)(92,861)
Changes in other regulatory liabilities(38,371)(19,115)
Changes in pension and other postretirement liabilities(270,144)(132,044)
Other(226,075)(400,064)
Net cash flow provided by operating activities2,370,166 2,117,947 
INVESTING ACTIVITIES
Construction/capital expenditures(3,175,559)(3,079,726)
Allowance for equity funds used during construction89,238 108,867 
Nuclear fuel purchases(177,385)(55,176)
Payment for purchase of assets(24,633)— 
Proceeds from sale of assets— 19,801 
Insurance proceeds received for property damages— 7,040 
Changes in securitization account791 (4,213)
Payments to storm reserve escrow account(2,244)(6,184)
Receipts from storm reserve escrow account40,647 — 
Decrease (increase) in other investments(9,821)30,370 
Litigation proceeds for reimbursement of spent nuclear fuel storage costs67,252 2,369 
Proceeds from nuclear decommissioning trust fund sales1,597,492 3,518,616 
Investment in nuclear decommissioning trust funds(1,661,660)(3,566,690)
Net cash flow used in investing activities(3,255,882)(3,024,926)
See Notes to Financial Statements.
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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt8,170,607 7,133,571 
Preferred stock of subsidiary— 33,486 
Treasury stock41,784 89,303 
Common stock— 607,650 
Retirement of long-term debt(5,386,227)(5,859,714)
Repurchase of preferred membership units— (50,000)
Changes in credit borrowings and commercial paper - net(548,522)(24,550)
Other(5,941)(9,175)
Dividends paid:
Common stock(558,121)(526,408)
Preferred stock(13,922)(12,328)
Net cash flow provided by financing activities1,699,658 1,381,835 
Net increase in cash and cash equivalents813,942 474,856 
Cash and cash equivalents at beginning of period425,722 480,975 
Cash and cash equivalents at end of period$1,239,664 $955,831 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$599,683 $584,622 
Income taxes($2,484)($8,649)
See Notes to Financial Statements.
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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$43,859 $34,242 
Temporary cash investments1,195,805 391,480 
Total cash and cash equivalents1,239,664 425,722 
Accounts receivable:
Customer844,794 595,509 
Allowance for doubtful accounts(73,426)(7,404)
Other122,674 219,870 
Accrued unbilled revenues453,378 400,617 
Total accounts receivable1,347,420 1,208,592 
Deferred fuel costs6,798 — 
Fuel inventory - at average cost146,084 145,476 
Materials and supplies - at average cost918,962 824,989 
Deferred nuclear refueling outage costs171,081 157,568 
Prepayments and other232,796 283,645 
TOTAL4,062,805 3,045,992 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds6,786,957 6,404,030 
Non-utility property - at cost (less accumulated depreciation)341,190 332,864 
Other465,903 496,452 
TOTAL7,594,050 7,233,346 
PROPERTY, PLANT, AND EQUIPMENT
Electric57,185,891 54,271,467 
Natural gas577,349 547,110 
Construction work in progress3,477,386 2,823,291 
Nuclear fuel613,298 677,181 
TOTAL PROPERTY, PLANT, AND EQUIPMENT61,853,924 58,319,049 
Less - accumulated depreciation and amortization23,852,928 23,136,356 
PROPERTY, PLANT, AND EQUIPMENT - NET38,000,996 35,182,693 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $147,813 as of September 30, 2020 and $239,219 as of December 31, 2019)
5,422,588 5,292,055 
Deferred fuel costs240,290 239,892 
Goodwill377,172 377,172 
Accumulated deferred income taxes76,247 64,461 
Other296,103 288,301 
TOTAL6,412,400 6,261,881 
TOTAL ASSETS$56,070,251 $51,723,912 
See Notes to Financial Statements.
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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$1,050,015 $795,012 
Notes payable and commercial paper1,398,205 1,946,727 
Accounts payable2,872,447 1,499,861 
Customer deposits408,764 409,171 
Taxes accrued440,224 233,455 
Interest accrued204,995 194,129 
Deferred fuel costs156,721 197,687 
Pension and other postretirement liabilities59,552 66,184 
Current portion of unprotected excess accumulated deferred income taxes63,261 76,457 
Other221,342 201,780 
TOTAL6,875,526 5,620,463 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued4,668,846 4,401,190 
Accumulated deferred investment tax credits200,914 207,113 
Regulatory liability for income taxes-net1,542,122 1,633,159 
Other regulatory liabilities2,026,867 1,961,005 
Decommissioning and asset retirement cost liabilities6,390,445 6,159,212 
Accumulated provisions495,999 534,028 
Pension and other postretirement liabilities2,534,753 2,798,265 
Long-term debt (includes securitization bonds of $209,177 as of September 30, 2020 and $297,981 as of December 31, 2019)
19,612,664 17,078,643 
Other695,866 852,749 
TOTAL38,168,476 35,625,364 
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund219,410 219,410 
EQUITY
Common stock, $.01 par value, authorized 500,000,000 shares; issued 270,035,180 shares in 2020 and 2019
2,700 2,700 
Paid-in capital6,535,541 6,564,436 
Retained earnings9,699,435 9,257,609 
Accumulated other comprehensive loss(390,420)(446,920)
Less - treasury stock, at cost (69,803,566 shares in 2020 and 70,886,400 shares in 2019)
5,075,417 5,154,150 
Total common shareholders' equity10,771,839 10,223,675 
Subsidiaries' preferred stock without sinking fund35,000 35,000 
TOTAL10,806,839 10,258,675 
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY$56,070,251 $51,723,912 
See Notes to Financial Statements.
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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2020
(Unaudited)
Common Shareholders’ Equity
Subsidiaries’ Preferred StockCommon
Stock		Treasury
Stock		Paid-in
Capital		Retained EarningsAccumulated Other Comprehensive LossTotal
(In Thousands)
Balance at December 31, 2019$35,000 $2,700 ($5,154,150)$6,564,436 $9,257,609 ($446,920)$10,258,675 
Implementation of accounting standards
— — — — (419)— (419)
Balance at January 1, 202035,000 2,700 (5,154,150)6,564,436 9,257,190 (446,920)10,258,256 
Consolidated net income (a)4,580 — — — 118,714 — 123,294 
Other comprehensive income— — — — — 47,933 47,933 
Common stock issuances related to stock plans
— — 73,580 (53,753)— — 19,827 
Common stock dividends declared— — — — (185,763)— (185,763)
Preferred dividend requirements of subsidiaries (a)
(4,580)— — — — — (4,580)
Balance at March 31, 2020$35,000 $2,700 ($5,080,570)$6,510,683 $9,190,141 ($398,987)$10,258,967 
Consolidated net income (a)4,580 — — — 360,533 — 365,113 
Other comprehensive income— — — — — 10,383 10,383 
Common stock issuances related to stock plans
— — 3,609 13,647 — — 17,256 
Common stock dividends declared— — — — (186,151)— (186,151)
Preferred dividend requirements of subsidiaries (a)
(4,580)— — — — — (4,580)
Balance at June 30, 2020$35,000 $2,700 ($5,076,961)$6,524,330 $9,364,523 ($388,604)$10,460,988 
Consolidated net income (a)4,580 — — — 521,119 — 525,699 
Other comprehensive loss— — — — — (1,816)(1,816)
Common stock issuances related to stock plans— — 1,544 11,211 — — 12,755 
Common stock dividends declared— — — — (186,207)— (186,207)
Preferred dividend requirements of subsidiaries (a)(4,580)— — — — — (4,580)
Balance at September 30, 2020$35,000 $2,700 ($5,075,417)$6,535,541 $9,699,435 ($390,420)$10,806,839 
See Notes to Financial Statements.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2020, second quarter 2020, and third quarter 2020 each includes $4.1 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.
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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2019
(Unaudited)
Common Shareholders’ Equity
Subsidiaries' Preferred StockCommon
Stock		Treasury
Stock		Paid-in
Capital		Retained EarningsAccumulated Other Comprehensive LossTotal
(In Thousands)
Balance at December 31, 2018$— $2,616 ($5,273,719)$5,951,431 $8,721,150 ($557,173)$8,844,305 
Implementation of accounting standards
— — — — 6,806 (6,806)— 
Balance at January 1, 2019— 2,616 (5,273,719)5,951,431 8,727,956 (563,979)8,844,305 
Consolidated net income (a)4,109 — — — 254,537 — 258,646 
Other comprehensive income— — — — — 12,827 12,827 
Common stock issuances related to stock plans
— — 62,537 (31,248)— — 31,289 
Common stock dividends declared— — — — (172,591)— (172,591)
Preferred dividend requirements of subsidiaries (a)
(4,109)— — — — — (4,109)
Balance at March 31, 2019$— $2,616 ($5,211,182)$5,920,183 $8,809,902 ($551,152)$8,970,367 
Consolidated net income (a)4,109 — — — 236,424 — 240,533 
Other comprehensive income— — — — — 120,748 120,748 
Settlement of equity forwards through common stock issuance— 84 — 607,566 — — 607,650 
Common stock issuance costs— — — (7)— — (7)
Common stock issuances related to stock plans
— — 23,391 11,791 — — 35,182 
Common stock dividends declared— — — — (172,861)— (172,861)
Preferred dividend requirements of subsidiaries (a)
(4,109)— — — — — (4,109)
Balance at June 30, 2019$— $2,700 ($5,187,791)$6,539,533 $8,873,465 ($430,404)$9,797,503 
Consolidated net income (a)4,219 — — — 365,240 — 369,459 
Other comprehensive income— — — — — 10,632 10,632 
Common stock issuances related to stock plans— — 29,166 13,476 — — 42,642 
Common stock dividends declared— — — — (180,956)— (180,956)
Subsidiary's preferred stock issuance35,000 — — — — — 35,000 
Preferred dividend requirements of subsidiaries (a)(4,219)— — — — — (4,219)
Balance at September 30, 2019$35,000 $2,700 ($5,158,625)$6,553,009 $9,057,749 ($419,772)$10,070,061 
See Notes to Financial Statements.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for the first quarter 2019, second quarter 2019, and third quarter 2019 each includes $4.1 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.
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SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedIncrease/
20202019(Decrease)%
(Dollars in Millions)
Utility electric operating revenues:
Residential$1,153 $1,155 ($2)— 
Commercial647 722 (75)(10)
Industrial590 686 (96)(14)
Governmental57 62 (5)(8)
Total billed retail2,447 2,625 (178)(7)
Sales for resale145 63 82 130 
Other75 125 (50)(40)
Total$2,667 $2,813 ($146)(5)
Utility billed electric energy sales (GWh):
Residential11,634 11,627 7 — 
Commercial7,791 8,499 (708)(8)
Industrial11,994 12,861 (867)(7)
Governmental660 705 (45)(6)
Total retail32,079 33,692 (1,613)(5)
Sales for resale4,881 3,025 1,856 61 
Total36,960 36,717 243 1 
Entergy Wholesale Commodities:
Operating revenues$214 $300 ($86)(29)
Billed electric energy sales (GWh)4,332 6,847 (2,515)(37)
Nine Months EndedIncrease/
20202019(Decrease)%
(Dollars in Millions)
Utility electric operating revenues:
Residential$2,742 $2,727 $15 1 
Commercial1,712 1,872 (160)(9)
Industrial1,723 1,929 (206)(11)
Governmental157 172 (15)(9)
Total billed retail6,334 6,700 (366)(5)
Sales for resale252 223 29 13 
Other322 357 (35)(10)
Total$6,908 $7,280 ($372)(5)
Utility billed electric energy sales (GWh):
Residential27,519 27,749 (230)(1)
Commercial20,106 21,764 (1,658)(8)
Industrial35,655 36,509 (854)(2)
Governmental1,826 1,932 (106)(5)
Total retail85,106 87,954 (2,848)(3)
Sales for resale11,109 10,009 1,100 11 
Total96,215 97,963 (1,748)(2)
Entergy Wholesale Commodities:
Operating revenues$747 $1,024 ($277)(27)
Billed electric energy sales (GWh)16,047 21,308 (5,261)(25)
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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.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.
    
As discussed in the Form 10-K, in December 2019 the U.S. Court of Federal Claims issued a judgment in the amount of $80 million in favor of Entergy Arkansas to resolve claims in the third round ANO damages case and issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) in the second round FitzPatrick damages case. Payment of both judgments was received from the U.S. Treasury in January 2020.

In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously capitalized.

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.

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Notes to Financial Statements
Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.


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.

Other Regulatory Assets

Hurricane Laura

In August 2020, Hurricane Laura caused severe damage to the Entergy distribution and transmission systems across Louisiana and Texas. The storm resulted in widespread power outages and, as a result of the storm’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Laura are currently estimated to be in the range of $1.5 billion to $1.7 billion, including $1.25 billion to $1.4 billion at Entergy Louisiana and $230 million to $260 million at Entergy Texas. Entergy also expects Utility revenues in 2020 to be adversely affected, primarily due to power outages resulting from the hurricane. Entergy is considering all available avenues to recover storm-related costs from Hurricane Laura, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $205 million, including $155 million at Entergy Louisiana and $40 million at Entergy Texas, and construction work in progress of approximately $1.295 billion, including $1.095 billion at Entergy Louisiana and $190 million at Entergy Texas. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is
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Notes to Financial Statements
an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

Regulatory activity regarding the Tax Cuts and Jobs Act

System Energy

In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC 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 were terminated in April 2019, and the hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision.

The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. Briefs opposing exceptions are scheduled for December 2020. The FERC will then review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

As discussed below in “Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million on the October 2020 bill. Comments, protests, and interventions in this filing are due in November 2020.
    
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Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2020, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01462 per kWh to $0.01052 per kWh. The redetermined rate became effective with the first billing cycle in April 2020 through the normal operation of the tariff.

Entergy Louisiana

In March 2020 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2016 through 2019. Discovery commenced in September 2020.

Entergy Mississippi

In November 2019, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation included $39.6 million of prior over-recovery flowing back to customers beginning February 2020. Entergy Mississippi’s balance in its deferred fuel account did not decrease as expected after implementation of the new factor. In an effort to assist customers during the COVID-19 pandemic, in May 2020, Entergy Mississippi requested an interim adjustment to the energy cost recovery rider to credit approximately $50 million from the over-recovered balance in the deferred fuel account to customers over four consecutive billing months. The MPSC approved this interim adjustment in May 2020 effective for June through September 2020 bills.

Entergy Texas

In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. In March 2020 an intervenor filed testimony proposing that the PUCT disallow: (1) $2 million in replacement power costs associated with generation outages during the reconciliation period; and (2) $24.4 million associated with the operation of the Spindletop natural gas storage facility during the reconciliation period.  In April 2020, Entergy Texas filed rebuttal testimony refuting all points raised by the intervenor.  In June 2020 the parties filed a stipulation and settlement agreement, which included a $1.2 million disallowance not associated with any particular issue raised by any party. The PUCT approved the settlement in August 2020.

In July 2020, Entergy Texas filed an application with the PUCT to implement an interim fuel refund of $25.5 million, including interest. Entergy Texas proposed that the interim fuel refund be implemented beginning with the first August 2020 billing cycle over a three-month period for smaller customers and in a lump sum amount in the billing month of August 2020 for transmission-level customers. The interim fuel refund was approved in July 2020, and Entergy Texas began refunds in August 2020.

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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 discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2020 Formula Rate Plan Filing

In July 2020, Entergy Arkansas filed with the APSC its 2020 formula rate plan filing to set its formula rate for the 2021 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2021, as amended through subsequent filings in the proceeding, and a netting adjustment for the historical year 2019. Entergy Arkansas’s earned rate of return on common equity is 8.22% for the 2021 projected year and 9.07% for the 2019 historical year. The total revenue change is based upon a deficiency of approximately $64.3 million for the 2021 projected year and approximately $23.9 million for the 2019 historical year netting adjustment. The total proposed formula rate plan rider revenue change for 2021 is $88.2 million to produce a target rate of return of 9.75% for the projected year and the historical year. 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 $72.6 million. In October 2020 other parties in the proceeding filed their errors and objections recommending certain adjustments that would reduce the initially-proposed $74.3 million revenue requirement increase, and Entergy Arkansas filed responsive testimony disputing these adjustments. In October 2020, Entergy Arkansas filed with the APSC a unanimous settlement agreement reached with the other parties that resolved all but one issue. As a result of the settlement agreement, Entergy Arkansas’s requested revenue increase is $68.4 million, which is below the $72.6 million cap constraint. The remaining issue to be litigated concerns the methodology used to account for historical year revenues in the netting adjustment. Two parties have proposed a new methodology that, if adopted, effectively would reduce Entergy Arkansas’s request to $0.9 million for the 2021 projected year. This remaining issue will go to hearing in November 2020 and a final decision by the APSC is expected in December 2020. Also with the formula rate plan filing, Entergy Arkansas is requesting an extension of the formula rate plan rider for a second five-year term. A decision by the APSC on the extension is requested before February 2021.

COVID-19 Orders

In April 2020, in light of the COVID-19 pandemic, the APSC issued an order requiring utilities, to the extent they had not already done so, to suspend service disconnections during the remaining pendency of the Arkansas Governor’s emergency declaration or until the APSC rescinds the directive. The order also authorizes utilities to establish a regulatory asset to record costs resulting from the suspension of service disconnections, directs that in future proceedings the APSC will consider whether the request for recovery of these regulatory assets is reasonable and necessary, and requires utilities to track and report the costs and any savings directly attributable to suspension of disconnects. In May 2020 the APSC approved Entergy Arkansas expanding deferred payment agreements to assist customers during the pandemic. Quarterly reporting began in August 2020 and the APSC ordered additional reporting in October 2020 regarding utilities’ transitional plans for ending the moratorium on service disconnects. As of September 30, 2020, Entergy Arkansas recorded a regulatory asset of $6.1 million for costs associated with the COVID-19 pandemic.

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Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. In June 2020, Entergy Louisiana submitted information to the LPSC to review the prudence of Entergy Louisiana’s management of the project. In August 2020 discovery commenced and a procedural schedule was established with a hearing in July 2021.

2018 Formula Rate Plan Filing

Commercial operation at Lake Charles Power Station commenced in March 2020. In March 2020, Entergy Louisiana filed an update to its 2018 formula rate plan evaluation report to include the estimated first-year revenue requirement of $108 million associated with the Lake Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of April 2020.

2019 Formula Rate Plan Filing

In May 2020, Entergy Louisiana filed with the LPSC its formula rate plan evaluation report for its 2019 calendar year operations. The 2019 test year evaluation report produced an earned return on common equity of 9.66%. As such, no change to base rider formula rate plan revenue is required. Although base rider formula rate plan revenue will not change as a result of this filing, overall formula rate plan revenues will increase by approximately $103 million. This outcome is driven by the removal of prior year credits associated with the sale of the Willow Glen Power Station and an increase in the transmission recovery mechanism. Also contributing to the overall change is an increase in legacy formula rate plan revenue requirements driven by legacy Entergy Louisiana capacity cost true-ups and higher annualized legacy Entergy Gulf States Louisiana revenues due to higher billing determinants, offset by reductions in MISO cost recovery mechanism and tax reform adjustment mechanism revenue requirements. In August 2020 the LPSC staff submitted a list of items for which it needs additional information to confirm the accuracy and compliance of the 2019 test year evaluation report. The LPSC staff objected to a proposed revenue neutral adjustment regarding a certain rider as being beyond the scope of permitted formula rate plan adjustments. Rates reflected in the May 2020 filing, with the exception of the revenue neutral rider adjustment, and as updated in an August 2020 filing, were implemented in September 2020, subject to refund. Entergy Louisiana is in the process of providing additional information and details on the May 2020 filing as requested by the LPSC staff.

Request for Extension and Modification of Formula Rate Plan

In May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. In its application, Entergy Louisiana seeks to maintain a 9.8% return on equity, with a bandwidth of 60 basis points above and below the midpoint, with a first-year midpoint reset. Entergy Louisiana also seeks to maintain its existing additional capacity mechanism, tax reform adjustment mechanism, transmission recovery mechanism, and the MISO cost recovery mechanism. Entergy Louisiana also seeks to add a distribution cost recovery mechanism which operates in substantially the same manner as the transmission recovery mechanism, seeks to utilize end of period rate base to calculate cost of service, and requests a deferral of certain expenses incurred for outside of right-of-way vegetation programs.


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Retail Rates - Gas

2017 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2018 Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. 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. In October 2019 the LPSC staff issued its report finding that Entergy Louisiana’s filing complied with the terms of the rate stabilization plan but recommending an additional refund of $0.7 million related to the Tax Act. In June 2020, the LPSC approved a joint report acknowledging Entergy Louisiana’s prior refunds and offsets for flood recovery costs, and required a further refund of $0.8 million, inclusive of carrying costs.

2018 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2019 Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. The filing of the evaluation report for the test year 2018 reflected an earned return on common equity of 2.69%. This earned return is below the earning sharing band of the gas rate stabilization plan and results in a rate increase of $2.8 million. Rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. In August 2020 the LPSC staff filed its report concurring with Entergy Louisiana’s calculation that the gas rate stabilization plan required a rate increase of $2.8 million. The LPSC accepted the staff’s report at its September 2020 meeting.

COVID-19 Orders

In April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. While the suspension of late fees and disconnects for non-pay was only extended until the first billing cycle after July 16, 2020, Entergy Louisiana has not yet resumed disconnections and continues to defer the associated costs. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of September 30, 2020, Entergy Louisiana recorded a regulatory asset of $27.4 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

Formula Rate Plan Filings

See the Form 10-K for revisions to Entergy Mississippi’s formula rate plan approved by the MPSC in December 2019. In January 2020 Entergy Mississippi began billing an interim capacity rate adjustment rider to recover the $59 million first-year annual revenue requirement associated with the non-fuel ownership costs of the Choctaw Generating Station. Also, effective with the April 2020 billing cycle, Entergy Mississippi implemented a rider to recover $22 million in vegetation management costs. Vegetation management costs were previously recovered through the formula rate plan.

In March 2020, Entergy Mississippi submitted its formula rate plan 2020 test year filing and 2019 look-back filing showing Entergy Mississippi’s earned return for the historical 2019 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2020 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $24.6 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base,
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within the formula rate plan bandwidth. The 2019 look-back filing compares actual 2019 results to the approved benchmark return on rate base and reflects the need for a $7.3 million interim increase in formula rate plan revenues. In accordance with the MPSC-approved revisions to the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2019 retail revenues, effective with the April 2020 billing cycle, subject to refund. In June 2020, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2020 test year filing showed that a $23.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. Pursuant to the joint stipulation, Entergy Mississippi’s 2019 look-back filing reflected an earned return on rate base of 6.75% in calendar year 2019, which is within the look-back bandwidth. As a result, there is no change in formula rate plan revenues in the 2019 look-back filing. In June 2020 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2020.

COVID-19 Orders

In March 2020 the MPSC issued an order suspending disconnections for a period of sixty days. The MPSC extended the order on disconnections through May 26, 2020. In April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. While the MPSC order on suspension of disconnections has expired, Entergy Mississippi has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy Mississippi recorded a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

Energy Efficiency

As discussed in the Form 10-K, in December 2019, Entergy New Orleans filed an application with the City Council seeking approval of an implementation plan for the Energy Smart energy efficiency program from April 2020 through December 2022. Entergy New Orleans proposed to recover the costs of the program through mechanisms previously approved by the City Council or through the energy efficiency cost recovery rider, which was approved in the 2018 combined rate case resolution. In February 2020 the City Council approved Entergy New Orleans’s application.

2018 Base Rate Case Filing

See the Form 10-K for discussion of the electric and gas base rate case filed in September 2018. In response to the City Council’s November 2019 resolution in the rate case, Entergy New Orleans made a compliance filing in December 2019 and also filed timely a petition for appeal and judicial review and for stay of or injunctive relief alleging that the resolution is unlawful in failing to produce just and reasonable rates. A hearing on the requested injunction was scheduled in Civil District Court for February 2020, but by joint motion of the City Council and Entergy New Orleans, the Civil District Court issued an order for a limited remand to the City Council to consider a potential agreement in principle/stipulation at its February 20, 2020 meeting. On February 17, 2020, Entergy New Orleans filed with the City Council an agreement in principle between Entergy New Orleans and the City Council’s advisors. On February 20, 2020, the City Council voted to approve the proposed agreement in principle and issued a resolution modifying the required treatment of certain accumulated deferred income taxes. As a result of the agreement in principle, the total annual revenue requirement reduction will be approximately $45 million ($42 million electric, including $29 million in rider reductions; and $3 million gas). Entergy New Orleans fully implemented the new rates in April 2020. In accordance with the provisions of the agreement in principle approved by the City Council related to the 2020 formula rate plan filing, Entergy New Orleans anticipates moving forward with dismissal of its judicial review petition in the Civil District Court.

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2020 Formula Rate Plan Filing

Entergy New Orleans’s first annual filing under the three-year formula rate plan approved by the City Council in November 2019 was originally due to be filed in April 2020. The authorized return on equity under the approved three-year formula rate plan is 9.35% for both electric and gas operations. The City Council approved several extensions of the deadline to allow additional time to assess the effects of the COVID-19 pandemic on the New Orleans community, Entergy New Orleans customers, and Entergy New Orleans itself. In October 2020 the City Council approved an agreement in principle filed by Entergy New Orleans that results in Entergy New Orleans foregoing its 2020 formula rate plan filing and shifting the three-year formula rate plan to filings in 2021, 2022, and 2023. Key provisions of the agreement in principle include: changing the lower of actual equity ratio or 50% equity ratio approved in the rate case to a hypothetical capital structure of 51% equity and 49% debt for the duration of the three-year formula rate plan; changing the 2% depreciation rate for the New Orleans Power Station approved in the rate case to 3%; retention of over-recovery of $2.2 million in rider revenues; recovery of $1.4 million of certain rate case expenses outside of the earnings band; recovery of the New Orleans Solar Station costs upon commercial operation; and Entergy New Orleans’s dismissal of its 2018 rate case appeal.

COVID-19 Orders

In March 2020, Entergy New Orleans voluntarily suspended customer disconnections for non-payment of utility bills through May 2020. Subsequently, the City Council ordered that the moratorium be extended to August 1, 2020. In May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. While the City Council moratorium on customer disconnections has expired, Entergy New Orleans has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy New Orleans recorded a regulatory asset of $8.4 million for costs associated with the COVID-19 pandemic.

In June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which is intended to provide temporary bill relief to customers who become unemployed during the COVID-19 pandemic. The program became effective July 1, 2020, and offers qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of September 30, 2020, credits of $1.9 million have been applied to customer bills under the City Council Cares Program.

Filings with the PUCT (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

In March 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $23.6 million annually, or $20.4 million in incremental annual DCRF revenue beyond Entergy Texas’s currently effective DCRF rider, based on its capital invested in distribution between January 1, 2019 and December 31, 2019. In May and June 2020 intervenors filed testimony recommending reductions in Entergy Texas’s annual revenue requirement of approximately $0.3 million and $4.1 million. The parties briefed the contested issues in this matter and a proposal for decision was issued in September 2020 recommending a $4.1 million revenue reduction related to non-Advanced Metering System meters included in the DCRF calculation. The parties filed exceptions to the proposal for decision and replies to those exceptions in September 2020. In October 2020 the PUCT issued a final order approving a $16.3 million incremental annual DCRF revenue increase.

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In October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019. In January 2020 the PUCT issued an order approving an unopposed settlement providing for recovery of the requested revenue requirement. Entergy Texas implemented the amended rider beginning with bills covering usage on and after January 23, 2020.

In October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020.

COVID-19 Orders

In March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of COVID-19. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. While the PUCT moratorium on disconnections has expired, Entergy Texas has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy Texas recorded a regulatory asset of $8.7 million for costs associated with the COVID-19 pandemic.

Generation Rider

In October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Montgomery County Power Station. In October 2020 the administrative law judge set a procedural schedule that will result in an administrative approval of Entergy Texas’s application in December 2020 if it is unopposed by parties to the proceeding.

System Agreement Cost Equalization Proceedings

Rough Production Cost Equalization Rates

Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings

As discussed in the Form 10-K, in April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision in the consolidated proceedings. Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings and the payments were made in May 2018. In April 2020 the FERC issued an order partially granting the LPSC’s rehearing request.  In the order the FERC reversed its prior finding and determined that the tax gain portion of the Waterford 3 financing accumulated deferred income tax should be included in the bandwidth calculation.  The order requires Entergy Services to redetermine bandwidth true-up payments and receipts for the 2010-2012 test years.

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In May 2020, Entergy and the LPSC both separately requested rehearing of the FERC’s April 2020 order partially granting the LPSC’s rehearing request. In June 2020 the FERC issued an order accepting the May 2018 true-up filing for the 2011-2014 rate filings. Also in June 2020, Entergy filed bandwidth true-up payments and receipts for the 2010-2012 test years to address the FERC’s April 2020 rehearing order:

Payments (Receipts)
(In Millions)
Entergy Arkansas($2.8)
Entergy Louisiana$2.3
Entergy Mississippi$0.2
Entergy New Orleans($0.1)
Entergy Texas$0.4

In July 2020, Entergy filed a correction to the June 2020 filing to address an error in the 2012 test year calculation. This resulted in additional payments of $1.5 million from Entergy Arkansas to Entergy Louisiana. In August 2020 both Entergy and the LPSC filed petitions for review, at the D.C. Circuit, of FERC’s orders in the consolidated 2011, 2012, 2013, and 2014 rate filings.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit by Entergy, the LPSC, and the APSC. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument is scheduled for December 2020.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In November 2019 the FERC issued an order denying the LPSC’s complaint. The order concluded that the settlement agreement approved by the FERC in December 2015 terminating the System Agreement barred the LPSC’s new complaint. In December 2019 the LPSC requested rehearing of the FERC’s November 2019 order, and in July 2020 the FERC issued an order dismissing the LPSC’s request for rehearing. In September 2020 the LPSC appealed the FERC’s orders dismissing the new opportunity sales complaint to the D.C. Circuit.

Also as discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application with the APSC requesting approval of a special rider tariff to recover the costs of its opportunity sales payments from its retail customers over a 24-month period. In January 2020 the Attorney General and Arkansas Electric Energy Consumers, Inc. filed testimony opposing the recovery by Entergy Arkansas of the opportunity sales payment but also claiming that certain components of the payment should be segregated and refunded to customers. In March 2020, Entergy Arkansas filed rebuttal testimony.

In July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. The order also directs Entergy Arkansas to refund to its retail customers within 30 days of the order the FERC-determined over-collection of $13.7 million, plus interest, associated with a recalculated bandwidth remedy. In addition to these primary findings, the order also denied the Attorney General’s request for Entergy Arkansas to prepare a compliance filing detailing all of the retail impacts from the opportunity sales and denied a request by the Arkansas Electric Energy Consumers to recalculate all costs using the revised responsibility ratio. Entergy Arkansas filed a motion for temporary stay of the 30-day requirement to allow Entergy Arkansas a reasonable opportunity to seek rehearing of the APSC order, but in July 2020 the APSC denied Entergy Arkansas’s request for a stay and directed Entergy Arkansas to refund to its retail ratepayers the component of the total FERC-determined
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opportunity sales payment that was associated with increased bandwidth remedy payments of $13.7 million, plus interest. The refunds were issued in the August 2020 billing cycle. While the APSC denied Entergy Arkansas’s stay request, Entergy Arkansas believes its actions were prudent and, therefore, the costs, including the $13.7 million, plus interest, are recoverable. In July 2020, Entergy Arkansas requested rehearing of the APSC order, which rehearing was denied by the APSC in August 2020. In September 2020, Entergy Arkansas filed a complaint in the U. S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. Entergy Arkansas expects to file a response opposing the APSC’s motion.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in November 2019, in a proceeding that did not involve System Energy, the FERC issued an order addressing the methodology for determining the return on equity applicable to transmission owners in MISO. Thereafter, the procedural schedule in the System Energy proceeding was amended to allow the participants to file supplemental testimony addressing the order in the MISO transmission owner proceeding (Opinion No. 569).

In February 2020 the LPSC, the MPSC and APSC, and the FERC trial staff filed supplemental testimony addressing Opinion No. 569 and how it would affect the return on equity evaluation for the two complaint periods concerning System Energy. For the first refund period, based on their respective interpretations and applications of the Opinion No. 569 methodology, the LPSC argues for an authorized return on equity for System Energy of 8.44%; the MPSC and APSC argue for an authorized return on equity of 8.41%; and the FERC trial staff argues for an authorized return on equity of 9.22%. For the second refund period and on a prospective basis, based on their respective interpretations and applications of the Opinion No. 569 methodology, the LPSC argues for an authorized return on equity for System Energy of 7.89%; the MPSC and APSC argue that an authorized return on equity of 8.01% may be appropriate; and the FERC trial staff argues for an authorized return on equity of 8.66%.

In April 2020, System Energy filed supplemental answering testimony addressing Opinion No. 569. System Energy argues that the Opinion No. 569 methodology is conceptually and analytically defective for purposes of establishing just and reasonable authorized return on equity determinations and proposes an alternative approach. As its primary recommendation, System Energy continues to support the return on equity determinations in its March 2019 testimony for the first refund period and its June 2019 testimony for the second refund period. Under the Opinion No. 569 methodology, System Energy calculates a “presumptively just and reasonable range” for the authorized return on equity for the first refund period of 8.57% to 9.52%, and for the second refund period of 8.28% to 9.11%. System Energy argues that these ranges are not just and reasonable results. Under its proposed alternative methodology, System Energy calculates an authorized return on equity of 10.26% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively.

In May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. Pursuant to the revised schedule, in June 2020, the LPSC, the MPSC and APSC, and the FERC trial staff filed supplemental testimony addressing Opinion No. 569-A and how it would affect the return on equity evaluation for the two complaint periods concerning System Energy. For the first refund period, based on their respective interpretations and applications of the Opinion No. 569-A methodology, the LPSC argues for an authorized return on equity for System Energy of 7.97%; the MPSC and APSC argue for an authorized return on equity of 9.24%; and the FERC trial staff argues for an authorized return on equity of 9.49%. For the second refund period and on a prospective basis, based on their respective interpretations and applications of the Opinion No. 569-A methodology, the LPSC argues for an authorized return on equity for System Energy of 7.78%; the MPSC and APSC argue that an authorized return on equity of 9.15% may be appropriate if the second complaint
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is not dismissed; and the FERC trial staff argues for an authorized return on equity of 9.09% if the second complaint is not dismissed.

Pursuant to the revised procedural schedule, in July 2020, System Energy filed supplemental testimony addressing Opinion No. 569-A. System Energy argues that strict application of the Opinion No. 569-A methodology produces results inconsistent with investor requirements and does not provide a sound basis on which to evaluate System Energy’s authorized return on equity. As its primary recommendation, System Energy argues for the use of a methodology that incorporates four separate financial models, including the constant growth form of the discounted cash flow model and the empirical capital asset pricing model. Based on application of its recommended methodology, System Energy argues for an authorized return on equity of 10.12% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively. Under the Opinion No. 569-A methodology, System Energy calculates an authorized return on equity of 9.44% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively.

The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing occurred in late-September through early-October 2020, and the initial decision is due in February 2021.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony sought refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions, and the cost of capital additions associated with the sale-leaseback interest, as well as interest on those amounts.

In June 2019 System Energy filed answering testimony arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save costs over the initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties.

In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for the liabilities associated with uncertain tax positions. The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable, but explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement re-billing calculation. Adjustments to depreciation expense in any re-billing under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for the liabilities associated with uncertain tax positions.  The LPSC seeks approximately $512 million, plus interest, which is approximately $185 million through September 30, 2020.  The FERC trial staff also filed rebuttal testimony in which it seeks refunds of a similar amount as the LPSC for the liabilities associated with uncertain tax
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positions.  The LPSC testimony also argued that adjustments to depreciation rates should affect rate base on a prospective basis only.

A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through September 30, 2020, is approximately $422 million, plus interest, which is approximately $106 million through September 30, 2020. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through September 30, 2020.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. In June 2020, System Energy, the LPSC, and the FERC trial staff filed briefs on exceptions, challenging several of the initial decision’s findings. System Energy’s brief on exceptions challenged the initial decision’s limitations on recovery of the lease renewal payments, its proposed rate base refund for the liabilities associated with uncertain tax positions, and its proposal to asymmetrically treat interest on bill corrections for depreciation expense adjustments. The LPSC’s and the FERC trial staff’s briefs on exceptions each challenged the initial decision’s allowance for recovery of the cost of service associated with the lease renewal based on the remaining net book value of the leased assets, its calculation of the remaining net book value of the leased assets, and the amount of the initial decision’s proposed rate base refund for the liabilities associated with uncertain tax positions. The LPSC’s brief on exceptions also challenged the initial decision’s proposal that depreciation expense adjustments include retroactive adjustments to rate base and its finding that section 203 of the Federal Power Act did not apply to the lease renewal. The FERC trial staff’s brief on exceptions also challenged the initial decision’s finding that the FERC need not institute a formal investigation into System Energy’s tariff. In October 2020, System Energy, the LPSC, the MPSC, the APSC, and the City Council filed briefs opposing exceptions. System Energy opposed the exceptions filed by the LPSC and the FERC trial staff. The LPSC, MPSC, APSC, City Council, and the FERC trial staff opposed the exceptions filed by System Energy. Also in October 2020 the MPSC, APSC, and the City Council filed briefs adopting the exceptions of the LPSC and the FERC trial staff. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

In addition, in September 2020, the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. The NOPA memorializes the IRS’s decision to adjust the 2015 consolidated federal income tax return of Entergy Corporation and certain of its subsidiaries, including System Energy, with regard to the uncertain decommissioning tax position. Pursuant to the audit resolution documented in the NOPA, the IRS allowed System Energy’s inclusion of $102 million of future nuclear decommissioning costs in System Energy’s cost of goods sold for the 2015 tax year, roughly 10% of the requested deduction, but disallowed the balance of the position. In
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September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020, the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA issued by the IRS in September 2020, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at FERC to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position. On a prospective basis beginning with the October 2020 bill, System Energy proposes to include the accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position as a credit to rate base under the Unit Power Sales Agreement. Comments, protests, and interventions in this filing are due in November 2020.

LPSC Authorization of Additional Complaints and September 2020 LPSC Complaint

In May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigation of rates charged by System Energy. The LPSC directive authorizes its staff to file complaints at FERC “necessary to address these rate issues, to request a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”

The first of the additional complaints was filed at the FERC by the LPSC, the APSC, the MPSC, and the City Council in September 2020. The new complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. Several of the filed rate allegations overlap with the previous complaints. The filed rate allegations not previously raised are that System Energy: failed to provide a rate base credit to customers for the “time value” of sale-leaseback lease payments collected from customers in advance of the time those payments were due to the owner-lessors; improperly included certain lease refinancing costs in rate base as prepayments; improperly included nuclear decommissioning outage costs in rate base; failed to include categories of accumulated deferred income taxes as a reduction to rate base; charged customers based on a higher equity ratio than would be appropriate due to excessive retained earnings; and did not correctly reflect money pool investments and imprudently invested cash into the money pool. The elements of the Unit Power Sales Agreement that the complaint alleges are unjust and unreasonable include: incentive and executive compensation, lack of an equity re-opener, lobbying, and private airplane travel. The new complaint also requests a rate investigation into the Unit Power Sales Agreement and System Energy’s billing practices pursuant to Section 206 of the Federal Power Act, including any issue relevant to the Unit Power Sales Agreement and its inputs. System Energy will file its answer opposing the new complaint in November 2020.

The operational prudence-related complaint has not been filed as of this date, and the LPSC directive did not set a date for the filing.

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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 September 30,
20202019
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings per share
Net income attributable to Entergy Corporation$521.1 200.2 $2.60 $365.2 198.9 $1.84 
Average dilutive effect of:
Stock options0.4 — 0.7 (0.01)
Other equity plans0.5 (0.01)0.9 (0.01)
Diluted earnings per share$521.1 201.1 $2.59 $365.2 200.5 $1.82 

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.5 million for the three months ended September 30, 2020.
For the Nine Months Ended September 30,
20202019
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings per share
Net income attributable to Entergy Corporation$1,000.4 200.1 $5.00 $856.2 193.9 $4.42 
Average dilutive effect of:
Stock options0.4 (0.01)0.5 (0.01)
Other equity plans0.5 (0.01)0.7 (0.02)
Equity forwards— — 0.6 (0.01)
Diluted earnings per share$1,000.4 201.0 $4.98 $856.2 195.7 $4.38 

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.5 million for the nine months ended September 30, 2020 and approximately 0.2 million for the nine months ended September 30, 2019.

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 $0.93 for the three months ended September 30, 2020 and $0.91 for the three months ended September 30, 2019. Dividends declared per common share were $2.79 for the nine months ended September 30, 2020 and $2.73 for the nine months ended September 30, 2019.


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Treasury Stock

During the nine months ended September 30, 2020, Entergy Corporation issued 1,082,834 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 nine months ended September 30, 2020.

Retained Earnings

On October 30, 2020, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on December 1, 2020, to holders of record as of November 12, 2020.

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 September 30, 2020 by component:
Cash flow
hedges
net
unrealized
gain (loss)		Pension
and
other
postretirement
liabilities		Net
unrealized
investment
gain (loss)		Total
Accumulated
Other
Comprehensive
Income (Loss)
(In Thousands)
Beginning balance, July 1, 2020$37,090 ($485,949)$60,255 ($388,604)
Other comprehensive income (loss) before reclassifications(4,964)— 181 (4,783)
Amounts reclassified from accumulated other comprehensive income (loss)(11,594)17,437 (2,876)2,967 
Net other comprehensive income (loss) for the period(16,558)17,437 (2,695)(1,816)
Ending balance, September 30, 2020$20,532 ($468,512)$57,560 ($390,420)


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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:
Cash flow
hedges
net
unrealized
gain (loss)		Pension
and
other
postretirement
liabilities		Net
unrealized
investment
gain (loss)		Total
Accumulated
Other
Comprehensive
Income (Loss)
(In Thousands)
Beginning balance, July 1, 2019$51,736 ($508,876)$26,736 ($430,404)
Other comprehensive income (loss) before reclassifications(5,190)— 8,350 3,160 
Amounts reclassified from accumulated other comprehensive income (loss)(14,913)25,464 (3,079)7,472 
Net other comprehensive income (loss) for the period(20,103)25,464 5,271 10,632 
Ending balance, September 30, 2019$31,633 ($483,412)$32,007 ($419,772)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2020 by component:
Cash flow
hedges
net
unrealized
gain (loss)		Pension
and
other
postretirement
liabilities		Net
unrealized
investment
gain (loss)		Total
Accumulated
Other
Comprehensive
Income (Loss)
(In Thousands)
Beginning balance, January 1, 2020$84,206 ($557,072)$25,946 ($446,920)
Other comprehensive income (loss) before reclassifications42,256 34,349 40,439 117,044 
Amounts reclassified from accumulated other comprehensive income (loss)(105,930)54,211 (8,825)(60,544)
Net other comprehensive income (loss) for the period(63,674)88,560 31,614 56,500 
Ending balance, September 30, 2020
$20,532 ($468,512)$57,560 ($390,420)


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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:
Cash flow
hedges
net
unrealized
gain (loss)		Pension
and
other
postretirement
liabilities		Net
unrealized
investment
gain (loss)		Total
Accumulated
Other
Comprehensive
Income (Loss)
(In Thousands)
Ending balance, December 31, 2018($23,135)($531,922)($2,116)($557,173)
Implementation of accounting standards(7,685)— 879 (6,806)
Beginning balance, January 1, 2019($30,820)($531,922)($1,237)($563,979)
Other comprehensive income (loss) before reclassifications122,481 — 37,724 160,205 
Amounts reclassified from accumulated other comprehensive income (loss)(60,028)48,510 (4,480)(15,998)
Net other comprehensive income (loss) for the period62,453 48,510 33,244 144,207 
Ending balance, September 30, 2019
$31,633 ($483,412)$32,007 ($419,772)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2020 and 2019:
Pension and Other
Postretirement Liabilities
20202019
(In Thousands)
Beginning balance, July 1,
$13,084 ($8,091)
Amounts reclassified from accumulated other comprehensive income (loss)(800)(969)
Net other comprehensive income (loss) for the period(800)(969)
Ending balance, September 30,
$12,284 ($9,060)

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2020 and 2019:
Pension and Other
Postretirement Liabilities
20202019
(In Thousands)
Beginning balance, January 1,$4,562 ($6,153)
Other comprehensive income (loss) before reclassifications10,050 — 
Amounts reclassified from accumulated other comprehensive income (loss)(2,328)(2,907)
Net other comprehensive income (loss) for the period7,722 (2,907)
Ending balance, September 30,
$12,284 ($9,060)

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2020 and 2019 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20202019
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$14,724 $18,925 Competitive business operating revenues
   Interest rate swaps(48)(48)Miscellaneous - net
Total realized gain (loss) on cash flow hedges14,676 18,877 
Income taxes(3,082)(3,964)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)$11,594 $14,913 
Pension and other postretirement liabilities
   Amortization of prior-service credit$5,682 $5,325 (a)
   Amortization of loss(27,620)(20,919)(a)
   Settlement loss(196)(16,630)(a)
Total amortization(22,134)(32,224)
Income taxes4,697 6,760 Income taxes
Total amortization (net of tax)($17,437)($25,464)
Net unrealized investment gain (loss)
Realized gain (loss)$4,550 $4,872 Interest and investment income
Income taxes(1,674)(1,793)Income taxes
Total realized investment gain (loss) (net of tax)$2,876 $3,079 
Total reclassifications for the period (net of tax)($2,967)($7,472)
    
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(a)These accumulated other comprehensive income (loss) components were 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 for the nine months ended September 30, 2020 and 2019 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20202019
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$134,233 $76,129 Competitive business operating revenues
   Interest rate swaps(145)(145)Miscellaneous - net
Total realized gain (loss) on cash flow hedges134,088 75,984 
Income taxes(28,158)(15,956)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)$105,930 $60,028 
Pension and other postretirement liabilities
   Amortization of prior-service credit$15,083 $15,977 (a)
   Amortization of loss(82,561)(58,888)(a)
   Settlement loss(196)(18,685)(a)
Total amortization(67,674)(61,596)
Income taxes13,463 13,086 Income taxes
Total amortization (net of tax)($54,211)($48,510)
Net unrealized investment gain (loss)
Realized gain (loss)$13,963 $7,088 Interest and investment income
Income taxes(5,138)(2,608)Income taxes
Total realized investment gain (loss) (net of tax)$8,825 $4,480 
Total reclassifications for the period (net of tax)$60,544 $15,998 

(a)These accumulated other comprehensive income (loss) components were 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 Louisiana for the three months ended September 30, 2020 and 2019 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20202019
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$1,695 $1,837 (a)
   Amortization of loss(417)(526)(a)
   Settlement loss(196)— (a)
Total amortization1,082 1,311 
Income taxes(282)(342)Income taxes
Total amortization (net of tax)800 969 
Total reclassifications for the period (net of tax)$800 $969 

(a)These accumulated other comprehensive income (loss) components were 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 nine months ended September 30, 2020 and 2019 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20202019
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$4,479 $5,511 (a)
   Amortization of loss(1,137)(1,578)(a)
   Settlement loss(196)— (a)
Total amortization3,146 3,933 
Income taxes(818)(1,026)Income taxes
Total amortization (net of tax)2,328 2,907 
Total reclassifications for the period (net of tax)$2,328 $2,907 

(a)These accumulated other comprehensive income (loss) components were 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)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million
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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 nine months ended September 30, 2020 was 2.50% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2020.
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$150$6$3,344

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 Registrant Subsidiaries (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.  As of September 30, 2020, Entergy Corporation had approximately $1,398 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2020 was 1.66%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2020 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate (a)Amount Drawn
as of
September 30, 2020		Letters of Credit
Outstanding as of
September 30, 2020
Entergy ArkansasApril 2021$25 million (b)1.27%$—$—
Entergy ArkansasSeptember 2024$150 million (c)1.27%$—$—
Entergy LouisianaSeptember 2024$350 million (c)1.27%$—$—
Entergy MississippiApril 2021$37.5 million (d)1.65%$—$—
Entergy MississippiApril 2021$35 million (d)1.65%$—$—
Entergy MississippiApril 2021$10 million (d)1.65%$—$—
Entergy New OrleansNovember 2021$25 million (c)1.42%$—$0.8 million
Entergy TexasSeptember 2024$150 million (c)1.65%$—$1.3 million

(a)The interest rate is the estimated interest rate as of September 30, 2020 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 0.225% 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.

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In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities primarily 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 September 30, 2020:
CompanyAmount of
Uncommitted Facility		Letter of Credit FeeMISO Letters of Credit
Issued as of
September 30, 2020 (a) (b)
Entergy Arkansas$25 million0.78%$3 million
Entergy Louisiana$125 million 0.78%$21.2 million
Entergy Mississippi$65 million0.78%$1 million
Entergy New Orleans$15 million1.00%$1 million
Entergy Texas$50 million0.70%$27.2 million

(a)As of September 30, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $1.9 million for Entergy Arkansas, $2.2 million for Entergy Louisiana, $0.7 million for Entergy Mississippi, and $0.2 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of September 30, 2020, in addition to the $1 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2020 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$175$—
Entergy New Orleans$150$5
Entergy Texas$200$54
System Energy$200$—

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 have commercial paper programs in place. Following is a summary as of September 30, 2020:
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CompanyExpiration
Date 		Amount
of
Facility		Weighted
Average Interest
Rate on
Borrowings (a)		Amount
Outstanding as of
September 30, 2020
(Dollars in Millions)
Entergy Arkansas VIESeptember 2022$801.97%$9.1
Entergy Louisiana River Bend VIESeptember 2022$1052.07%$30.9
Entergy Louisiana Waterford VIESeptember 2022$1051.94%$51.4
System Energy VIESeptember 2022$1201.63%$75.7

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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.

The commitment fees on the credit facilities are 0.125% 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 were included in debt on the respective balance sheets as of September 30, 2020 as follows:
CompanyDescriptionAmount
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
2.51% Series V due June 2027
$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
3.42% Series J due April 2021
$100 million

In October 2020, System Energy VIE issued $90 million of 2.05% Series K secured notes due September 2027. System Energy VIE expects to use the proceeds to redeem $100 million of 3.42% Series J secured notes due April 2021.

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 Corporation)

In May 2020, Entergy Corporation issued $600 million of 2.80% Series senior notes due June 2030 and $600 million of 3.75% Series senior notes due June 2050. Entergy Corporation used the proceeds, together with other funds, to repay, prior to maturity, its $450 million of 5.125% Series senior notes due September 2020, a portion of its outstanding commercial paper, a portion of outstanding borrowings on its $3.5 billion credit facility, and for general corporate purposes.

In August 2020, Entergy Corporation issued $800 million of 0.90% Series senior notes due September 2025. Entergy Corporation used the proceeds, together with other funds, to repay a portion of its outstanding
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commercial paper, to repay a portion of outstanding borrowings on its $3.5 billion credit facility, and for general corporate purposes.

(Entergy Arkansas)

In March 2020, Entergy Arkansas issued $100 million of 4.00% Series mortgage bonds due June 2028. Entergy Arkansas used the proceeds for general corporate purposes.

In September 2020, Entergy Arkansas issued $675 million of 2.65% Series mortgage bonds due June 2051. Entergy Arkansas used a portion of the proceeds to repay, prior to maturity, $200 million of 4.90% Series mortgage bonds due December 2052 and $125 million of 4.75% Series mortgage bonds due June 2063, and expects to use a portion of the remaining proceeds to repay, at maturity, some or all of its $350 million of 3.75% Series mortgage bonds due February 2021 and for general corporate purposes.

(Entergy Louisiana)

In March 2020, Entergy Louisiana issued $350 million of 2.90% Series mortgage bonds due March 2051. Entergy Louisiana used the proceeds, together with other funds, to repay borrowings of $100 million on its $350 million credit facility and for general corporate purposes.

In March 2020, Entergy Louisiana issued $300 million of 4.20% Series mortgage bonds due September 2048. Entergy Louisiana used the proceeds, together with other funds, to repay, prior to maturity, its $250 million of 3.95% Series mortgage bonds due October 2020 and for general corporate purposes.

(Entergy Mississippi)

In May 2020, Entergy Mississippi issued $170 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds for general corporate purposes.

(Entergy New Orleans)

In March 2020, Entergy New Orleans issued $62 million of 3.75% Series mortgage bonds due March 2040 and $78 million of 3.00% Series mortgage bonds due March 2025. Entergy New Orleans used the proceeds to repay short-term debt, to finance a portion of the construction of the New Orleans Power Station, and for general corporate purposes.

(Entergy Texas)

In March 2020, Entergy Texas issued $175 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas used the proceeds, together with other funds, to finance a portion of the construction of the Montgomery County Power Station, to repay borrowings of $100 million on its $150 million credit facility, and for general corporate purposes.

In October 2020, Entergy Texas issued $600 million of 1.75% Series mortgage bonds due March 2031. Entergy Texas used a portion of the proceeds to repay, prior to maturity, its $135 million of 5.625% Series mortgage bonds due June 2064, and expects to use a portion of the remaining proceeds to repay, at or prior to maturity, some or all of its $125 million of 2.55% Series mortgage bonds due June 2021, and for general corporate purposes.
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Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2020 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$20,662,679 $22,925,661 
Entergy Arkansas$4,280,229 $4,648,483 
Entergy Louisiana$7,651,976 $8,756,480 
Entergy Mississippi$1,780,310 $1,997,431 
Entergy New Orleans$674,832 $663,388 
Entergy Texas$2,047,749 $2,318,713 
System Energy$592,611 $615,602 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2019 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$17,873,655 $19,059,950 
Entergy Arkansas$3,517,208 $3,747,914 
Entergy Louisiana$7,303,669 $7,961,168 
Entergy Mississippi$1,614,129 $1,709,505 
Entergy New Orleans$560,906 $523,846 
Entergy Texas$1,922,956 $2,090,215 
System Energy$548,107 $565,209 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.


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.

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Stock Options

Entergy granted options on 530,716 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2020 with a fair value of $11.45 per option.  As of September 30, 2020, there were options on 2,424,013 shares of common stock outstanding with a weighted-average exercise price of $89.66.  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 September 30, 2020.  The aggregate intrinsic value of the stock options outstanding as of September 30, 2020 was $38.7 million.

The following table includes financial information for outstanding stock options for the three months ended September 30, 2020 and 2019:
20202019
(In Millions)
Compensation expense included in Entergy’s net income$1.0 $0.9 
Tax benefit recognized in Entergy’s net income$0.3 $0.2 
Compensation cost capitalized as part of fixed assets and materials and supplies$0.4 $0.4 

The following table includes financial information for outstanding stock options for the nine months ended September 30, 2020 and 2019:
20202019
(In Millions)
Compensation expense included in Entergy’s net income$3.0 $2.9 
Tax benefit recognized in Entergy’s net income$0.8 $0.7 
Compensation cost capitalized as part of fixed assets and materials and supplies$1.2 $1.0 

Other Equity Awards

In January 2020 the Board approved and Entergy granted 313,805 restricted stock awards and 134,853 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective as of January 30, 2020 and were valued at $131.72 per share, which was the closing price of Entergy’s common stock on that date.  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 three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date.  

In addition, long-term incentive awards were also 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. For the 2020-2022 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on a cumulative adjusted earnings per share metric.  The performance units were granted as of January 30, 2020 and eighty percent were valued at $169.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $131.72 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.
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The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2020 and 2019:
20202019
(In Millions)
Compensation expense included in Entergy’s net income$8.9 $8.4 
Tax benefit recognized in Entergy’s net income$2.2 $2.1 
Compensation cost capitalized as part of fixed assets and materials and supplies$3.6 $3.0 

The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2020 and 2019:
20202019
(In Millions)
Compensation expense included in Entergy’s net income$27.9 $25.6 
Tax benefit recognized in Entergy’s net income$7.1 $6.5 
Compensation cost capitalized as part of fixed assets and materials and supplies$10.8 $8.8 


NOTE 6.  RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2020 and 2019, included the following components:
20202019
(In Thousands)
Service cost - benefits earned during the period$40,366 $33,553 
Interest cost on projected benefit obligation59,930 73,261 
Expected return on assets(103,534)(103,751)
Amortization of net loss87,516 60,395 
Settlement charges32,429 16,291 
Net pension costs$116,707 $79,749 
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Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2020 and 2019, included the following components:
20202019
(In Thousands)
Service cost - benefits earned during the period$121,124 $100,766 
Interest cost on projected benefit obligation181,528 221,114 
Expected return on assets(310,664)(311,494)
Amortization of net loss262,034 177,233 
Settlement charges32,429 17,591 
Net pension costs$286,451 $205,210 

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2020 and 2019, included the following components:
2020Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$6,580 $8,788 $2,015 $663 $1,529 $1,970 
Interest cost on projected benefit obligation11,054 12,614 3,234 1,457 2,686 2,753 
Expected return on assets(19,531)(22,415)(5,783)(2,627)(5,483)(4,687)
Amortization of net loss17,092 16,663 4,747 2,005 3,295 4,277 
Settlement charges19,708 6,527 2,299 — 3,895 — 
Net pension cost$34,903 $22,177 $6,512 $1,498 $5,922 $4,313 

2019Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$5,260 $7,284 $1,629 $568 $1,350 $1,549 
Interest cost on projected benefit obligation14,175 15,882 4,068 1,873 3,613 3,364 
Expected return on assets(20,177)(22,651)(5,969)(2,696)(5,862)(4,678)
Amortization of net loss11,840 11,643 3,104 1,529 2,334 2,850 
Net pension cost$11,098 $12,158 $2,832 $1,274 $1,435 $3,085 
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The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2020 and 2019, included the following components:
2020Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$19,712 $26,376 $6,061 $1,989 $4,621 $5,900 
Interest cost on projected benefit obligation33,920 38,296 9,914 4,369 8,250 8,381 
Expected return on assets(58,775)(67,219)(17,297)(7,881)(16,455)(14,013)
Amortization of net loss50,886 49,917 14,243 6,015 9,825 12,835 
Settlement charges19,708 6,527 2,299 — 3,895 — 
Net pension cost$65,451 $53,897 $15,220 $4,492 $10,136 $13,103 

2019Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$15,782 $21,852 $4,887 $1,706 $4,050 $4,649 
Interest cost on projected benefit obligation42,525 47,646 12,204 5,621 10,837 10,091 
Expected return on assets(60,529)(67,955)(17,905)(8,089)(17,586)(14,032)
Amortization of net loss35,522 34,929 9,313 4,588 7,002 8,550 
Net pension cost$33,300 $36,472 $8,499 $3,826 $4,303 $9,258 

Non-Qualified Net Pension Cost

Entergy recognized $4.5 million and $4.6 million in pension cost for its non-qualified pension plans in the third quarters of 2020 and 2019, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2019 were settlement charges of $955 thousand related to the payment of lump sum benefits out of the plan. Entergy recognized $13.6 million and $16.3 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2020 and 2019, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 were settlement charges of $4.6 million 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 third quarters of 2020 and 2019:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2020$83 $37 $90 $7 $118 
2019$67 $38 $69 $5 $119 
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The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2020 and 2019:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2020$249 $111 $270 $21 $354 
2019$211 $122 $257 $16 $365 

Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2020 and 2019, included the following components:
20202019
(In Thousands)
Service cost - benefits earned during the period$6,231 $4,675 
Interest cost on accumulated postretirement benefit obligation (APBO)6,888 11,975 
Expected return on assets(10,182)(9,562)
Amortization of prior service credit(8,985)(8,844)
Amortization of net loss1,005 358 
Net other postretirement benefit income($5,043)($1,398)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2020 and 2019, included the following components:
 20202019
 (In Thousands)
Service cost - benefits earned during the period$18,263 $14,025 
Interest cost on accumulated postretirement benefit obligation (APBO)21,708 35,925 
Expected return on assets(30,692)(28,686)
Amortization of prior service credit(23,892)(26,532)
Amortization of net loss2,478 1,074 
Net other postretirement benefit cost income($12,135)($4,194)


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The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the third quarters of 2020 and 2019, included the following components:

2020Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$933 $1,524 $372 $114 $306 $321 
Interest cost on APBO1,164 1,497 372 186 477 276 
Expected return on assets(4,260)— (1,287)(1,344)(2,403)(735)
Amortization of prior service credit(396)(1,695)(444)(228)(939)(282)
Amortization of net (gain) loss162 (81)48 9 231 33 
Net other postretirement benefit cost (income) ($2,397)$1,245 ($939)($1,263)($2,328)($387)

2019Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$591 $1,160 $262 $92 $236 $243 
Interest cost on APBO1,807 2,666 670 395 854 476 
Expected return on assets(3,991)— (1,199)(1,237)(2,276)(697)
Amortization of prior service credit(1,238)(1,837)(439)(171)(561)(363)
Amortization of net (gain) loss144 (174)181 58 121 89 
Net other postretirement benefit cost (income)($2,687)$1,815 ($525)($863)($1,626)($252)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2020 and 2019, included the following components:
2020Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$2,694 $4,471 $1,095 $333 $915 $936 
Interest cost on APBO3,545 4,717 1,166 599 1,536 859 
Expected return on assets(12,846)— (3,881)(4,043)(7,241)(2,218)
Amortization of prior service credit(1,453)(4,479)(1,209)(532)(2,428)(783)
Amortization of net (gain) loss379 (361)125 (20)674 86 
Net other postretirement benefit cost (income)($7,681)$4,348 ($2,704)($3,663)($6,544)($1,120)

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2019Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period
$1,773 $3,480 $786 $276 $708 $729 
Interest cost on APBO
5,421 7,998 2,010 1,185 2,562 1,428 
Expected return on assets
(11,973)— (3,597)(3,711)(6,828)(2,091)
Amortization of prior service credit
(3,714)(5,511)(1,317)(513)(1,683)(1,089)
Amortization of net (gain) loss
432 (522)543 174 363 267 
Net other postretirement benefit cost (income)
($8,061)$5,445 ($1,575)($2,589)($4,878)($756)

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 third quarters of 2020 and 2019:
2020Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $5,739 ($57)$5,682 
Amortization of net loss(26,462)(327)(831)(27,620)
Settlement loss(196)— — (196)
($26,658)$5,412 ($888)($22,134)
Entergy Louisiana
Amortization of prior service credit$— $1,695 $— $1,695 
Amortization of net gain (loss)(497)81 (1)(417)
Settlement loss(196)— — ($196)
($693)$1,776 ($1)$1,082 
2019Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $5,375 ($50)$5,325 
Amortization of net gain (loss)(20,686)308 (541)(20,919)
Settlement loss(16,257)— (373)(16,630)
($36,943)$5,683 ($964)($32,224)
Entergy Louisiana
Amortization of prior service credit$— $1,837 $— $1,837 
Amortization of net gain (loss)(699)174 (1)(526)
($699)$2,011 ($1)$1,311 
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Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2020 and 2019:
2020Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $15,255 ($172)$15,083 
Amortization of net loss(79,387)(680)(2,494)(82,561)
Settlement loss(196)— — (196)
($79,583)$14,575 ($2,666)($67,674)
Entergy Louisiana
Amortization of prior service credit$— $4,479 $— $4,479 
Amortization of net gain (loss)(1,495)361 (3)(1,137)
Settlement loss(196)— — (196)
($1,691)$4,840 ($3)$3,146 

2019Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $16,125 ($148)$15,977 
Amortization of net gain (loss)(58,156)923 (1,655)(58,888)
Settlement loss(17,557)— (1,128)(18,685)
($75,713)$17,048 ($2,931)($61,596)
Entergy Louisiana
Amortization of prior service credit$— $5,511 $— $5,511 
Amortization of net gain (loss)(2,096)522 (4)(1,578)
($2,096)$6,033 ($4)$3,933 

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”, 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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health
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reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change have been reflected in the March 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law.

Qualified Pension Settlement Cost

In the third quarter of 2020, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees exceeded the sum of the Plan’s 2020 service and interest cost, resulting in a settlement cost of $32.4 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas participate in the Entergy Corporation Retirement Plan for Bargaining Employees and incurred settlement costs of $19.7 million, $6.5 million, $2.3 million, and $3.9 million, respectively. The settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $416.3 million to its qualified pension plans in 2020.  As of September 30, 2020, Entergy had contributed $189.5 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 2020:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2020 pension contributions$73,905 $74,572 $15,664 $6,301 $6,901 $20,406 
Pension contributions made through September 2020$43,032 $30,988 $8,691 $2,353 $2,517 $10,635 
Remaining estimated pension contributions to be made in 2020$30,873 $43,584 $6,973 $3,948 $4,384 $9,771 


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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 September 30, 2020 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the third quarters of 2020 and 2019 was as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsEntergy
(In Thousands)
2020
Operating revenues$2,689,186 $214,371 $25 ($14)$2,903,568 
Income taxes$143,622 $12,321 ($6,499)$— $149,444 
Consolidated net income (loss)$555,583 $30,773 ($28,758)($31,899)$525,699 
2019
Operating revenues$2,840,222 $300,363 $9 ($19)$3,140,575 
Income taxes$71,698 ($30,855)($11,642)$— $29,201 
Consolidated net income (loss)$581,964 ($140,501)($40,105)($31,899)$369,459 

Entergy’s segment financial information for the nine months ended September 30, 2020 and 2019 was as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsEntergy
(In Thousands)
2020
Operating revenues$6,996,876 $746,629 $54 ($25)$7,743,534 
Income taxes$164,383 $6,249 ($3,266)$— $167,366 
Consolidated net income (loss)$1,228,333 $5,523 ($124,056)($95,695)$1,014,105 
Total assets as of September 30, 2020$53,825,473 $3,743,167 $519,264 ($2,017,653)$56,070,251 
2019
Operating revenues$7,392,641 $1,023,757 $11 ($42)$8,416,367 
Income taxes$81,283 $25,763 ($33,616)$— $73,430 
Consolidated net income (loss)$1,150,863 ($68,804)($117,725)($95,695)$868,639 
Total assets as of December 31, 2019$49,557,664 $4,154,961 $514,020 ($2,502,733)$51,723,912 

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment.
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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 shut down and sell all of the remaining plants in the merchant nuclear 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 third quarters of 2020 and 2019 were comprised of the following:
20202019
Employee retention and severance
expenses and other benefits-related costs		Contracted economic development costsTotalEmployee retention and severance
expenses and other benefits-related costs		Contracted economic development costsTotal
 (In Millions)
Balance as of July 1,$153 $14 $167 $181 $14 $195 
Restructuring costs accrued19 — 19 14 — 14 
Cash paid out1 — 1 86 — 86 
Balance as of September 30,$171 $14 $185 $109 $14 $123 
    
In addition, Entergy Wholesale Commodities incurred $4 million in the third quarter 2020 and $8 million in the third quarter 2019 of impairment and other related charges associated with these strategic decisions and transactions.

Total restructuring charges for the nine months ended September 30, 2020 and 2019 were comprised of the following:
20202019
Employee retention and severance
expenses and other benefits-related costs		Contracted economic development costsTotalEmployee retention and severance
expenses and other benefits-related costs		Contracted economic development costsTotal
 (In Millions)
Balance as of January 1,$129 $14 $143 $179 $14 $193 
Restructuring costs accrued57 — 57 70 — 70 
Cash paid out15 — 15 140 — 140 
Balance as of September 30,
$171 $14 $185 $109 $14 $123 

In addition, Entergy Wholesale Commodities incurred $16 million in the nine months ended September 30, 2020 and $98 million in the nine months ended September 30, 2019 of impairment and other related charges associated with these strategic decisions and transactions.

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Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $70 million in 2020, of which $57 million has been incurred as of September 30, 2020, and a total of approximately $55 million from 2021 through 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.

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 may also use 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.

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Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2020 is approximately 6 months.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2020, of which approximately 62% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2020 is 3.5 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 guarantee, 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 September 30, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $22 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $11 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $1 million in cash collateral and $98 million in letters of credit were required to be posted by it 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 natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options 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 price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy had executed natural gas swaps and options as of September 30, 2020 was 3.5 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of September 30, 2020 was 6 months for Entergy Mississippi and 6 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2020 was 38,070,000 MMBtu for Entergy, including 25,560,000 MMBtu for Entergy Louisiana, 11,506,000 MMBtu for Entergy Mississippi, and 1,004,000 MMBtu for Entergy New
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Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2020 was 92,491 GWh for Entergy, including 22,239 GWh for Entergy Arkansas, 43,454 GWh for Entergy Louisiana, 10,353 GWh for Entergy Mississippi, 4,243 GWh for Entergy New Orleans, and 11,889 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 September 30, 2020 and December 31, 2019. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of September 30, 2020 and for Entergy Mississippi as of December 31, 2019.

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The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2020 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.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Business
(In Millions)
Derivatives designated as hedging instruments
Assets:
Electricity swaps and optionsPrepayments and other (current portion)$29($2)$27Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options
Other current liabilities
(current portion)
$1($1)$—Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Electricity swaps and optionsPrepayments and other (current portion)$1$—$1Entergy Wholesale Commodities
Natural gas swaps and optionsPrepayments and other (current portion)$3$—$3Utility
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$1$—$1Utility
Financial transmission rightsPrepayments and other$17$—$17Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and optionsOther non-current liabilities (non-current portion)$1$—$1Utility
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The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2019 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.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Business
(In Millions)
Derivatives designated as hedging instruments    
Assets:    
Electricity swaps and optionsPrepayments and other (current portion)$92($1)$91Entergy Wholesale Commodities
Electricity swaps and optionsOther deferred debits and other assets (non-current portion)$17$—$17Entergy Wholesale Commodities
Liabilities:    
Electricity swaps and optionsOther current liabilities (current portion)$1($1)$—Entergy Wholesale Commodities
Derivatives not designated as hedging instruments    
Assets:    
Electricity swaps and optionsPrepayments and other (current portion)$11($1)$10Entergy Wholesale Commodities
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$1$—$1Utility
Financial transmission rightsPrepayments and other$10$—$10Utility and Entergy Wholesale Commodities
Liabilities:    
Electricity swaps and optionsOther current liabilities (current portion)$2($2)$—Entergy Wholesale Commodities
Natural gas swaps and optionsOther current liabilities (current portion)$5$—$5Utility
Natural gas swaps and optionsOther non-current liabilities (non-current portion)$2$—$2Utility

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet
(d)Excludes cash collateral in the amount of $1 million posted as of September 30, 2020 and $11 million posted and $1 million held as of December 31, 2019. Also excludes letters of credit in the amount of $5 million posted and $22 million held as of September 30, 2020 and $98 million held as of December 31, 2019.

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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 September 30, 2020 and 2019 were as follows:
InstrumentAmount of gain (loss)
recognized in other
comprehensive
income		Income Statement locationAmount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a)
(In Millions)(In Millions)
2020
Electricity swaps and options($6)Competitive businesses operating revenues$15
2019
Electricity swaps and options($7)Competitive businesses operating revenues$19

(a)Before taxes of $3 million and $4 million for the three months ended September 30, 2020 and 2019, respectively

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2020 and 2019 were as follows:
InstrumentAmount of gain (loss)
recognized in other
comprehensive income		Income Statement locationAmount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a)
(In Millions)(In Millions)
2020
Electricity swaps and options$54Competitive businesses operating revenues$134
2019
Electricity swaps and options$145Competitive businesses operating revenues$76

(a)Before taxes of $28 million and $16 million for the nine months ended September 30, 2020 and 2019, respectively

Based on market prices as of September 30, 2020, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $27 million of net unrealized gains.  Approximately $27 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other
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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 September 30, 2020 and 2019 were as follows:
InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2020
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$33
Electricity swaps and options (c)Competitive business operating revenues$2
2019
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($2)
Financial transmission rightsPurchased power expense(b)$25
Electricity swaps and options (c)Competitive business operating revenues$1

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2020 and 2019 were as follows:
InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2020
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$61
Electricity swaps and options (c)Competitive business operating revenues$—
2019
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($9)
Financial transmission rightsPurchased power expense(b)$78
Electricity swaps and options (c)Competitive business operating revenues$4

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(a)Due to regulatory treatment, the natural gas swaps and options 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 and options 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)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2020 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.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
Assets:
Natural gas swaps and optionsPrepayments and other$2.2$—$2.2Entergy Louisiana
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$0.9$—$0.9Entergy Louisiana
Natural gas swapsPrepayments and other$1.1$—$1.1Entergy Mississippi
Financial transmission rightsPrepayments and other$6.4($0.1)$6.3Entergy Arkansas
Financial transmission rightsPrepayments and other$7.1($0.1)$7.0Entergy Louisiana
Financial transmission rightsPrepayments and other$0.8$—$0.8Entergy Mississippi
Financial transmission rightsPrepayments and other$0.3($0.2)$0.1
Entergy New Orleans
Financial transmission rightsPrepayments and other$2.3$—$2.3Entergy Texas
Liabilities:
Natural gas swaps and optionsOther non-current liabilities$1.3$—$1.3Entergy Louisiana

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The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2019 were as follows:
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
Assets:
Natural gas swaps and optionsOther deferred debits and other assets$0.8$—$0.8Entergy Louisiana
Financial transmission rightsPrepayments and other$3.4($0.1)$3.3Entergy Arkansas
Financial transmission rightsPrepayments and other$4.5$—$4.5Entergy Louisiana
Financial transmission rightsPrepayments and other$0.8$—$0.8Entergy Mississippi
Financial transmission rightsPrepayments and other$0.3$—$0.3Entergy New Orleans
Financial transmission rightsPrepayments and other$1.0($0.1)$0.9Entergy Texas
Liabilities:
Natural gas swaps and optionsOther current liabilities$2.4$—$2.4Entergy Louisiana
Natural gas swaps and optionsOther non-current liabilities$2.2$—$2.2Entergy Louisiana
Natural gas swapsOther current liabilities$2.3$—$2.3Entergy Mississippi
Natural gas swapsOther current liabilities$0.2$—$0.2Entergy 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 September 30, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $1.9 million for Entergy Arkansas, $2.2 million for Entergy Louisiana, $0.7 million for Entergy Mississippi, and $0.2 million for Entergy New Orleans. As of December 31, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi.


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The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2020 and 2019 were as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2020
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$1.4(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.5)(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($0.5)(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$3.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$1.3(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$0.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$22.8(b)Entergy Texas
2019
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale($1.7)(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($0.3)(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($0.1)(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$3.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$14.4(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$1.9(b)Entergy Mississippi
Financial transmission rightsPurchased power expense($0.3)(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.5(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 nine months ended September 30, 2020 and 2019 were as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2020
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$1.4(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($4.0)(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($0.5)(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$14.7(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$13.9(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$0.7(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$0.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$30.5(b)Entergy Texas
2019
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale($3.6)(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($5.5)(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.1(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$15.4(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$40.9(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.3(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$2.2(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$13.6(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options 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 and options are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the
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estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  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 and gas swaps and options valued using observable inputs.

•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
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liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight 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 Office of Corporate Risk Oversight is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the 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 Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight 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 a quarterly 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 Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and
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assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2020 and December 31, 2019.  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.
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,196 $— $— $1,196 
Decommissioning trust funds (a):
Equity securities959 — — 959 
Debt securities (b)1,091 2,036 — 3,127 
Common trusts (c)2,702 
Power contracts— — 28 28 
Securitization recovery trust account47 — — 47 
Escrow accounts420 — — 420 
Gas hedge contracts3 1 — 4 
Financial transmission rights— — 17 17 
$3,716 $2,037 $45 $8,500 
Liabilities:
Gas hedge contracts$— $1 $— $1 

2019Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$391 $— $— $391 
Decommissioning trust funds (a):    
Equity securities905 — — 905 
Debt securities1,139 1,824 — 2,963 
Common trusts (c)2,536 
Power contracts— — 118 118 
Securitization recovery trust account47 — — 47 
Escrow accounts459 — — 459 
Gas hedge contracts— 1 — 1 
Financial transmission rights— — 10 10 
 $2,941 $1,825 $128 $7,430 
Liabilities:    
Gas hedge contracts$5 $2 $— $7 

(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.
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(b)The decommissioning trust funds fair value presented herein does not include the recognition of a credit loss valuation allowance of $0.6 million on debt securities due to the adoption of ASU 2016-13. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.
(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2020 and 2019:
20202019
Power ContractsFinancial transmission rightsPower ContractsFinancial transmission rights
(In Millions)
Balance as of July 1,$49 $22 $72 $29 
Total gains (losses) for the period (a)
Included in earnings2 1 1 — 
Included in other comprehensive income(6)— (7)— 
Included as a regulatory liability/asset— 27 — 12 
Settlements(17)(33)(18)(25)
Balance as of September 30,$28 $17 $48 $16 

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was ($3.7) million for the three months ended September 30, 2020 and ($1.2) million for the three months ended September 30, 2019.

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 nine months ended September 30, 2020 and 2019:
20202019
Power ContractsFinancial transmission rightsPower ContractsFinancial transmission rights
(In Millions)
Balance as of January 1,$118 $10 ($31)$15 
Total gains (losses) for the period (a)
Included in earnings— 1 4 — 
Included in other comprehensive income54 — 145 — 
Included as a regulatory liability/asset— 44 — 44 
Issuances of financial transmission rights— 23 — 35 
Settlements(144)(61)(70)(78)
Balance as of September 30,$28 $17 $48 $16 

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was ($0.2) million for the nine months ended September 30, 2020 and ($4.7) million for the nine months ended September 30, 2019.
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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 September 30, 2020:
Transaction TypeFair ValueSignificant
Unobservable Inputs		Range
from
Average
%		Effect on
Fair Value
(In Millions)(In Millions)
Power contracts - electricity swaps$28Unit contingent discount+/-4.75%$3

The values of financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

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 TypePositionChange to InputEffect on
Fair Value
Unit contingent discountElectricity swapsSellIncrease (Decrease)Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2020 and December 31, 2019.  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
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$597.8 $— $— $597.8 
Decommissioning trust funds (a):
Equity securities15.1 — — 15.1 
Debt securities105.6 327.6 — 433.2 
Common trusts (b)720.5 
Financial transmission rights— — 6.3 6.3 
$718.5 $327.6 $6.3 $1,772.9 

2019Level 1Level 2Level 3Total
(In Millions)
Assets:
Decommissioning trust funds (a):
Equity securities$0.6 $— $— $0.6 
Debt securities108.7 304.1 — 412.8 
Common trusts (b)687.9 
Securitization recovery trust account4.0 — — 4.0 
Financial transmission rights— — 3.3 3.3 
$113.3 $304.1 $3.3 $1,108.6 
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Entergy Louisiana
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$251.8 $— $— $251.8 
Decommissioning trust funds (a):
Equity securities9.4 — — 9.4 
Debt securities162.8 463.6 — 626.4 
Common trusts (b)1,014.6 
Escrow accounts256.7 — — 256.7 
Securitization recovery trust account9.6 — — 9.6 
Gas hedge contracts2.2 0.9 — 3.1 
Financial transmission rights— — 7.0 7.0 
$692.5 $464.5 $7.0 $2,178.6 
Liabilities:
Gas hedge contracts$— $1.3 $— $1.3 

2019Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$1.5 $— $— $1.5 
Decommissioning trust funds (a):    
Equity securities4.3 — — 4.3 
Debt securities180.8 420.7 — 601.5 
Common trusts (b)958.0 
Escrow accounts295.9 — — 295.9 
Securitization recovery trust account3.7 — — 3.7 
Gas hedge contracts— 0.8 — 0.8 
Financial transmission rights— — 4.5 4.5 
 $486.2 $421.5 $4.5 $1,870.2 
Liabilities:
Gas hedge contracts$2.4 $2.2 $— $4.6 

Entergy Mississippi
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$43.0 $— $— $43.0 
Escrow accounts80.3 — — 80.3 
Gas hedge contracts1.1 — — 1.1 
Financial transmission rights— — 0.8 0.8 
$124.4 $— $0.8 $125.2 

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2019Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$51.6 $— $— $51.6 
Escrow accounts80.2 — — 80.2 
Financial transmission rights— — 0.8 0.8 
 $131.8 $— $0.8 $132.6 
Liabilities:
Gas hedge contracts$2.3 $— $— $2.3 

Entergy New Orleans
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Securitization recovery trust account$6.2 $— $— $6.2 
Escrow accounts83.0 — — 83.0 
Financial transmission rights— — 0.1 0.1 
$89.2 $— $0.1 $89.3 

2019Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$6.0 $— $— $6.0 
Securitization recovery trust account2.0 — — 2.0 
Escrow accounts82.6 — — 82.6 
Financial transmission rights— — 0.3 0.3 
$90.6 $— $0.3 $90.9 
Liabilities:
Gas hedge contracts$0.2 $— $— $0.2 

Entergy Texas
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Securitization recovery trust account$30.9 $— $— $30.9 
Financial transmission rights— — 2.3 2.3 
$30.9 $— $2.3 $33.2 
2019Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$12.9 $— $— $12.9 
Securitization recovery trust account37.7 — — 37.7 
Financial transmission rights— — 0.9 0.9 
$50.6 $— $0.9 $51.5 
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System Energy
2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$11.8 $— $— $11.8 
Decommissioning trust funds (a):
Equity securities8.5 — — 8.5 
Debt Securities179.1 241.7 — 420.8 
Common trusts (b)685.2 
$199.4 $241.7 $— $1,126.3 

2019Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$68.4 $— $— $68.4 
Decommissioning trust funds (a):
Equity securities13.3 — — 13.3 
Debt securities176.3 209.9 — 386.2 
Common trusts (b)654.6 
$258.0 $209.9 $— $1,122.5 

(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.

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 September 30, 2020.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of July 1,$6.1 $12.5 $1.1 ($0.2)$2.6 
Gains (losses) included as a regulatory liability/asset5.4 (2.4)1.0 0.4 22.5 
Settlements(5.2)(3.1)(1.3)(0.1)(22.8)
Balance as of September 30,$6.3 $7.0 $0.8 $0.1 $2.3 

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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 September 30, 2019.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of July 1,$8.2 $15.6 $2.8 $2.0 $0.6 
Gains (losses) included as a regulatory liability/asset(0.8)7.9 0.6 (1.6)6.2 
Settlements(3.5)(14.4)(1.9)0.3 (5.5)
Balance as of September 30,$3.9 $9.1 $1.5 $0.7 $1.3 

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 nine months ended September 30, 2020.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$3.3 $4.5 $0.8 $0.3 $0.9 
Issuances of financial transmission rights6.5 13.2 1.4 (0.1)2.4 
Gains (losses) included as a regulatory liability/asset11.2 3.2 (0.7)0.7 29.5 
Settlements(14.7)(13.9)(0.7)(0.8)(30.5)
Balance as of September 30,$6.3 $7.0 $0.8 $0.1 $2.3 

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 nine months ended September 30, 2019.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$3.4 $8.3 $2.2 $1.3 ($0.5)
Issuances of financial transmission rights9.6 18.7 3.9 2.7 0.1 
Gains (losses) included as a regulatory liability/asset6.3 23.0 0.6 (1.1)15.3 
Settlements(15.4)(40.9)(5.2)(2.2)(13.6)
Balance as of September 30,$3.9 $9.1 $1.5 $0.7 $1.3 


NOTE 9.  DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

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, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

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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 unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants 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 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.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2020 on equity securities still held as of September 30, 2020 were $250 million and $142 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 debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of September 30, 2020 and December 31, 2019 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2020
Debt Securities (a)$2,581 $201 $2 
2019
Debt Securities (a)$2,456 $96 $6 

(a)Debt securities presented herein do not include the $546 million and $507 million of debt securities held in the wholly-owned registered investment company as of September 30, 2020 and December 31, 2019, respectively, which are not accounted for as available-for-sale.

The unrealized gains/(losses) above are reported before deferred taxes of $31 million as of September 30, 2020 and $13 million as of December 31, 2019 for debt securities. The amortized cost of available-for-sale debt securities was $2,382 million as of September 30, 2020 and $2,366 million as of December 31, 2019.  As of September 30, 2020, available-for-sale debt securities had an average coupon rate of approximately 3.09%, an average duration of approximately 7.13 years, and an average maturity of approximately 10.41 years.


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The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of September 30, 2020 and December 31, 2019:
September 30, 2020December 31, 2019
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$206 $2 $404 $5 
More than 12 months2 — 38 1 
Total$208 $2 $442 $6 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2020 and December 31, 2019 were as follows:
20202019
(In Millions)
Less than 1 year$24 $128 
1 year - 5 years718 807 
5 years - 10 years761 666 
10 years - 15 years347 125 
15 years - 20 years135 126 
20 years+596 604 
Total$2,581 $2,456 

During the three months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $156 million and $407 million, respectively.  During the three months ended September 30, 2020 and 2019, gross gains of $9 million and $11 million, respectively, and gross losses of $0.2 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $832 million and $1,133 million, respectively.  During the nine months ended September 30, 2020 and 2019, gross gains of $38 million and $20 million, respectively, and gross losses of $4 million and $3 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 September 30, 2020 were $588 million for Indian Point 1, $742 million for Indian Point 2, $986 million for Indian Point 3, and $538 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2019 were $556 million for Indian Point 1, $701 million for Indian Point 2, $930 million for Indian Point 3, and $498 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

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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 September 30, 2020 and December 31, 2019 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2020
Debt Securities$433.2 $29.5 $0.2 
2019
Debt Securities$412.8 $9.9 $2.6 

The amortized cost of available-for-sale debt securities was $403.8 million as of September 30, 2020 and $405.4 million as of December 31, 2019.  As of September 30, 2020, available-for-sale debt securities had an average coupon rate of approximately 2.60%, an average duration of approximately 6.91 years, and an average maturity of approximately 8.21 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2020 on equity securities still held as of September 30, 2020 were $57.2 million and $27 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 available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of September 30, 2020 and December 31, 2019:
September 30, 2020December 31, 2019
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$26.8 $0.2 $104.8 $2.5 
More than 12 months— — 7.7 0.1 
Total$26.8 $0.2 $112.5 $2.6 

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2020 and December 31, 2019 were as follows:
 20202019
 (In Millions)
Less than 1 year$13.6 $44.1 
1 year - 5 years102.0 109.1 
5 years - 10 years177.5 156.0 
10 years - 15 years75.8 31.3 
15 years - 20 years26.7 23.8 
20 years+37.6 48.5 
Total$433.2 $412.8 

During the three months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $14.6 million and $45.5 million, respectively.  During the three months ended September 30, 2020 and 2019, gross gains of $1.7 million and $2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2020, gross losses of $3.6 thousand were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses.

During the nine months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $80.9 million and $78.7 million, respectively.  During the nine months ended September 30, 2020 and 2019, gross gains of $7.5 million and $2.1 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2020 and December 31, 2019 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2020
Debt Securities$626.4 $50.5 $0.5 
2019
Debt Securities$601.5 $29.3 $0.8 

The amortized cost of available-for-sale debt securities was $576.5 million as of September 30, 2020 and $573 million as of December 31, 2019.  As of September 30, 2020, the available-for-sale debt securities had an average coupon rate of approximately 3.73%, an average duration of approximately 7.30 years, and an average maturity of approximately 12.97 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2020 on equity securities still held as of September 30, 2020 were $80.2 million and $40.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500
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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 length of time that the securities had been in a continuous loss position, were as follows as of September 30, 2020 and December 31, 2019:
September 30, 2020December 31, 2019
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$43.7 $0.5 $71.2 $0.8 
More than 12 months0.8 — 7.9 — 
Total$44.5 $0.5 $79.1 $0.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2020 and December 31, 2019 were as follows:
20202019
(In Millions)
Less than 1 year$7.7 $40.7 
1 year - 5 years122.9 142.0 
5 years - 10 years147.8 132.4 
10 years - 15 years95.1 39.8 
15 years - 20 years61.8 49.2 
20 years+191.1 197.4 
Total$626.4 $601.5 

During the three months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $30.6 million and $59.7 million, respectively.  During the three months ended September 30, 2020 and 2019, gross gains of $1.4 million and $2.5 million, respectively, and gross losses of $1.3 thousand and $29 thousand, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $132.1 million and $155.4 million, respectively.  During the nine months ended September 30, 2020 and 2019, gross gains of $6.3 million and $4.2 million, respectively, and gross losses of $0.7 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.


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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, 2020 and December 31, 2019 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2020
Debt Securities$420.8 $31.6 $0.4 
2019
Debt Securities$386.2 $15.1 $0.3 

The amortized cost of available-for-sale debt securities was $389.7 million as of September 30, 2020 and $371.4 million as of December 31, 2019.  As of September 30, 2020, available-for-sale debt securities had an average coupon rate of approximately 2.93%, an average duration of approximately 7.50 years, and an average maturity of approximately 11.20 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2020 on equity securities still held as of September 30, 2020 were $54.4 million and $25.7 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 available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of September 30, 2020 and December 31, 2019:
September 30, 2020December 31, 2019
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$28.7 $0.4 $56.9 $0.3 
More than 12 months— — 0.3 — 
Total$28.7 $0.4 $57.2 $0.3 

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2020 and December 31, 2019 were as follows:
20202019
(In Millions)
Less than 1 year($1.6)$8.5 
1 year - 5 years163.1 154.6 
5 years - 10 years107.0 92.3 
10 years - 15 years27.5 13.4 
15 years - 20 years4.9 14.4 
20 years+119.9 103.0 
Total$420.8 $386.2 

During the three months ended September 30, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $24.1 million and $108.6 million, respectively.  During the three months ended September 30, 2020 and 2019, gross gains of $1.6 million and $1.7 million, respectively, and gross losses of $9.9 thousand and $0.2 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, 2020 and 2019, proceeds from the dispositions of available-for-sale securities amounted to $189.7 million and $238.4 million, respectively.  During the nine months ended September 30, 2020 and 2019, gross gains of $8.6 million and $3.6 million, respectively, and gross losses of $0.4 million and $0.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy implemented ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, effective January 1, 2020. In accordance with the new standard, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of September 30, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities was $0.6 million. Entergy did not record any impairments of available-for-sale debt securities for the three and nine months ended September 30, 2020.

Other-than-temporary impairments and unrealized gains and losses

Prior to the implementation of ASU 2016-13 on January 1, 2020, Entergy evaluated 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 had occurred.  The assessment of whether an investment in a debt security suffered an other-than-temporary impairment was based on whether Entergy had the intent to sell or more likely than not would have been required to sell the debt security before recovery of its amortized costs.  Further, if Entergy did not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment was considered to have occurred and it was 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 nine months ended September 30, 2019. 
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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.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries 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 their respective regulatory commissions. 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 manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:
Three Months
Ended September 30,		Nine Months
Ended September 30,
2020201920202019
(In Millions)
Entergy$17 $96 $61 $219 
Entergy Arkansas($2)$41 $9 $99 
Entergy Louisiana$8 $17 $24 $31 
Entergy New Orleans$1 $7 $6 $9 
Entergy Texas$10 $31 $22 $73 
System Entergy$— $— $— $7 

Other Tax Matters

In accordance with ASC 718, “Compensation - Stock Compensation,” Entergy and the Registrant Subsidiaries recognized excess tax deductions as a reduction of income tax expense in the first quarter 2020. Due to the vesting and exercise of certain Entergy stock-based awards, Entergy recorded a permanent tax reduction of approximately $24.7 million, including $4.8 million for Entergy Arkansas, $8.6 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $2.7 million for Entergy Texas, and $1.3 million for System Energy.

In the first quarter 2020, Entergy and the IRS agreed upon and settled on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million.  As a result of the settlement, the position was partially sustained and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of liabilities for uncertain tax positions in excess of the agreed-upon settlement.  Entergy recorded an increase to income tax expense of $26 million primarily resulting from the reduction of the deferred tax asset, associated with utilization of the net operating loss as a result of the settlement. This adjustment recorded by Entergy also accounted for the tax rate change of the Tax Cuts and Jobs Act.  As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order.

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Tax Accounting Methods

As discussed in Note 3 to the financial statements in the Form 10-K, in 2015, System Energy and Entergy Louisiana adopted a new method of accounting for income tax return purposes in which nuclear decommissioning liabilities are treated as production costs of electricity includable in cost of goods sold. The new method resulted in a reduction of taxable income of $1.2 billion for System Energy and $2.2 billion for Entergy Louisiana in 2015. In the third quarter 2020 the IRS issued Notices of Proposed Adjustment concerning this uncertain tax position allowing System Energy to include $102 million of its decommissioning liability in cost of goods sold, and Entergy Louisiana to include $221 million of its decommissioning liability in cost of goods sold. The Notices of Proposed Adjustment will not be appealed.

As a result of System Energy being allowed to include part of its decommissioning liability in cost of goods sold, System Energy and Entergy recorded a deferred tax liability of $26 million. System Energy also recorded federal and state taxes payable of $402 million; on a consolidated basis, however, Entergy utilized tax loss carryovers to offset the federal taxable income adjustment and accordingly did not record federal taxes payable as a result of the outcome of this uncertain tax position.

As a result of Entergy Louisiana being allowed to include part of its decommissioning liability in cost of goods sold, Entergy Louisiana and Entergy recorded a deferred tax liability of $60 million. Both Entergy Louisiana and Entergy utilized tax loss carryovers to offset the taxable income adjustment and accordingly did not record taxes payable as a result of the outcome of this uncertain tax position.

The partial disallowance of this uncertain tax position to include the decommissioning liability in cost of goods sold resulted in a $1.5 billion decrease in the balance of unrecognized tax benefits related to federal and state taxes for Entergy. Additionally, both System Energy and Entergy Louisiana recorded a reduction to their balances of unrecognized tax benefits for federal and state taxes of $461 million and $1.1 billion, respectively.

The tax treatment of Entergy Louisiana’s accrued regulatory liabilities associated with the Vidalia purchased power agreement and business combination guaranteed customer credits, which are discussed in Note 2 to the financial statements in the Form 10-K, has been resolved in a manner that results in a $190 million increase to previously reported taxable income. Entergy Louisiana and Entergy utilized tax loss carryovers to offset the taxable income adjustment, however, which allowed both Entergy Louisiana and Entergy to reduce their balances of federal and state unrecognized tax benefits by $74 million.

Coronavirus Aid, Relief, and Economic Security Act

In response to the economic impacts of the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) into law on March 27, 2020. The CARES Act provisions that result in the most significant opportunities for tax relief to Entergy and the Registrant Subsidiaries are permitting a five-year carryback of 2018-2020 net operating losses, removing the 80 percent limitation on the carryback of 2018-2020 net operating losses, increasing the limitation on interest expense deductibility for 2019 and 2020, accelerating available refunds for minimum tax credit carryforwards, modifying limitations on charitable contributions during 2020, and delaying the payment of employer payroll taxes. Based on current estimates, Entergy could defer approximately $64 million of 2020 payroll tax payments, which would be payable in two installments of $32 million on December 31, 2021 and December 31, 2022.



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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 September 30, 2020 were $1.4 billion for Entergy, $50.4 million for Entergy Arkansas, $1.1 billion for Entergy Louisiana, $24.1 million for Entergy Mississippi, $6.4 million for Entergy New Orleans, $204.3 million for Entergy Texas, and $18.0 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2019 were $406 million for Entergy, $67.9 million for Entergy Arkansas, $115.1 million for Entergy Louisiana, $34.2 million for Entergy Mississippi, $18.4 million for Entergy New Orleans, $88.1 million for Entergy Texas, and $23.2 million for System Energy. See Note 2 to the financial statements herein for discussion of construction expenditures related to Hurricane Laura recorded as of September 30, 2020.


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, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2020 and in the three months ended September 30, 2019. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2020 and in the nine months ended September 30, 2019.


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NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Utility:
Residential$1,153,220 $1,154,455 
Commercial647,119 722,334 
Industrial589,648 686,122 
Governmental56,710 61,697 
    Total billed retail2,446,697 2,624,608 
Sales for resale (a)145,187 63,082 
Other electric revenues (b)69,122 115,352 
    Revenues from contracts with customers2,661,006 2,803,042 
Other revenues (c)5,799 9,892 
    Total electric revenues2,666,805 2,812,934 
Natural gas22,357 27,269 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)195,184 282,420 
Other revenues (c)19,222 17,952 
    Total competitive businesses revenues214,406 300,372 
    Total operating revenues$2,903,568 $3,140,575 




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Entergy’s total revenues for the nine months ended September 30, 2020 and 2019 are as follows:
20202019
(In Thousands)
Utility:
Residential$2,742,118 $2,727,367 
Commercial1,712,179 1,871,416 
Industrial1,723,367 1,928,857 
Governmental156,251 172,280 
    Total billed retail6,333,915 6,699,920 
Sales for resale (a)251,674 222,834 
Other electric revenues (b)288,009 326,771 
    Revenues from contracts with customers6,873,598 7,249,525 
Other revenues (c)34,401 30,158 
    Total electric revenues6,907,999 7,279,683 
Natural gas88,829 112,916 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)586,906 923,288 
Other revenues (c)159,800 100,480 
    Total competitive businesses revenues746,706 1,023,768 
    Total operating revenues$7,743,534 $8,416,367 
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The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2020 and 2019 were as follows:
2020Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$274,496 $413,442 $161,031 $83,242 $221,009 
Commercial137,764 248,276 109,432 50,565 101,082 
Industrial138,037 316,876 34,062 7,219 93,454 
Governmental5,133 17,449 10,917 17,187 6,024 
    Total billed retail555,430 996,043 315,442 158,213 421,569 
Sales for resale (a)64,494 81,843 29,535 9,057 67,643 
Other electric revenues (b)17,677 35,097 9,612 2,403 5,685 
Revenues from contracts with customers637,601 1,112,983 354,589 169,673 494,897 
Other revenues (c)6,788 (2,766)1,907 (161)25 
    Total electric revenues644,389 1,110,217 356,496 169,512 494,922 
Natural gas— 9,805 — 12,552 — 
    Total operating revenues$644,389 $1,120,022 $356,496 $182,064 $494,922 

2019Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$253,627 $426,012 $177,785 $81,468 $215,563 
Commercial162,564 277,071 131,596 56,430 94,673 
Industrial156,024 376,595 44,054 8,613 100,836 
Governmental5,907 18,731 12,551 19,030 5,478 
    Total billed retail578,122 1,098,409 365,986 165,541 416,550 
Sales for resale (a)58,953 81,664 9,569 6,876 16,704 
Other electric revenues (b)47,085 37,521 20,499 2,537 9,177 
Revenues from contracts with customers
684,160 1,217,594 396,054 174,954 442,431 
Other revenues (c)3,366 4,280 2,678 1,784 446 
    Total electric revenues687,526 1,221,874 398,732 176,738 442,877 
Natural gas— 9,803 — 17,466 — 
    Total operating revenues$687,526 $1,231,677 $398,732 $194,204 $442,877 

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The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2020 and 2019 were as follows:
2020Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$665,355 $974,407 $400,495 $187,561 $514,300 
Commercial355,112 659,641 295,823 132,470 269,133 
Industrial345,378 974,419 106,327 17,632 279,611 
Governmental13,508 50,984 31,043 43,512 17,204 
    Total billed retail1,379,353 2,659,451 833,688 381,175 1,080,248 
Sales for resale (a)142,590 243,071 62,383 27,245 89,459 
Other electric revenues (b)82,811 120,209 45,448 7,166 36,426 
Revenues from contracts with customers1,604,754 3,022,731 941,519 415,586 1,206,133 
Other revenues (c)13,314 1,628 6,853 12,256 319 
    Total electric revenues1,618,068 3,024,359 948,372 427,842 1,206,452 
Natural gas— 37,962 — 50,867 — 
    Total operating revenues$1,618,068 $3,062,321 $948,372 $478,709 $1,206,452 


2019Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$621,208 $980,443 $423,395 $192,165 $510,156 
Commercial412,697 715,983 331,785 156,152 254,799 
Industrial396,515 1,108,193 120,490 24,353 279,306 
Governmental15,776 53,547 33,108 53,916 15,933 
    Total billed retail1,446,196 2,858,166 908,778 426,586 1,060,194 
Sales for resale (a)213,038 248,827 19,377 25,680 48,251 
Other electric revenues (b)107,599 130,269 47,887 8,093 37,329 
Revenues from contracts with customers1,766,833 3,237,262 976,042 460,359 1,145,774 
Other revenues (c)9,434 15,564 7,671 4,414 1,157 
    Total electric revenues1,776,267 3,252,826 983,713 464,773 1,146,931 
Natural gas— 44,498 — 68,418 — 
    Total operating revenues$1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.
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(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.
(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in its allowance for doubtful accounts, as shown below:
EntergyEntergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of December 31, 2019$7.4 $1.2 $1.9 $0.6 $3.2 $0.5 
Provisions (a)66.9 10.6 26.3 11.0 8.8 10.2 
Write-offs(8.6)(1.8)(3.5)(1.2)(1.0)(1.1)
Recoveries7.7 2.2 2.5 1.0 1.0 1.0 
Balance as of September 30, 2020$73.4 $12.2 $27.2 $11.4 $12.0 $10.6 
(a)Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $51 million for Entergy, $6.1 million for Entergy Arkansas, $20.9 million for Entergy Louisiana, $8.4 million for Entergy Mississippi, $7.7 million for Entergy New Orleans, and $7.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements herein for discussion of the COVID-19 orders issued by retail regulators.
The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
________________

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.

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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 September 30, 2020, 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 September 30, 2020 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.



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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of the COVID-19 pandemic.

Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income decreased $13.9 million primarily due to lower volume/weather, partially offset by lower other operation and maintenance expenses.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income increased $1.5 million primarily due to lower other operation and maintenance expenses, a formula rate plan regulatory provision recorded in the first quarter 2019 to reflect the historical year netting adjustment, higher retail electric price, and lower nuclear refueling outage expenses, substantially offset by lower volume/weather and higher depreciation and amortization expenses.

Operating Revenues

Third Quarter 2020 Compared to Third Quarter 2019

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$687.5 
Fuel, rider, and other revenues that do not significantly affect net income(48.6)
Volume/weather(40.8)
Retail electric price2.6 
Return of unprotected excess accumulated deferred income taxes to customers43.7 
2020 operating revenues$644.4 

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to a decrease of 228 GWh, or 4%, in billed electricity usage, including decreased commercial and industrial usage as a result of the COVID-19 pandemic, and the effect of less favorable weather on residential sales, partially offset by an increase in residential usage as a result of the
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COVID-19 pandemic. Entergy Arkansas continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of January 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

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. In third quarter 2020, $2.3 million was collected from customers as a result of a true-up to the tax adjustment rider as compared to $41.4 million returned to customers in third quarter 2019. There is no effect on net income as the reduction in operating revenues in each period was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$1,776.3 
Fuel, rider, and other revenues that do not significantly affect net income(182.5)
Volume/weather(74.1)
Retail electric price9.2 
Return of unprotected excess accumulated deferred income taxes to customers89.2 
2020 operating revenues$1,618.1 

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to a decrease of 754 GWh, or 5%, in billed electricity usage, including decreased commercial and industrial usage as a result of the COVID-19 pandemic, and the effect of less favorable weather on residential sales, partially offset by an increase in residential usage as a result of the COVID-19 pandemic. Entergy Arkansas continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of January 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

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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. In the nine months ended September 30, 2020, $9.5 million was returned to customers as compared to $98.7 million in the nine months ended September 30, 2019. There is no effect on net income as the reduction in operating revenues in each period was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Other Income Statement Variances

Third Quarter 2020 Compared to Third Quarter 2019

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $5 million in non-nuclear generation expenses primarily due to lower long-term service agreement expenses;
•a decrease of $3.9 million in nuclear generation expenses primarily due to lower nuclear labor costs, including contract labor, and a lower scope of work performed in 2020 as compared to 2019, in part as a result of the COVID-19 pandemic;
•the deferral in third quarter 2020 of $3 million in estimated incremental bad debt expenses resulting from the COVID-19 pandemic that were incurred in second quarter 2020; and
•a decrease of $2.2 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services.

Other regulatory charges (credits) in the third quarter 2020 included $13.6 million in amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing.

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.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

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

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $22.2 million in non-nuclear generation expenses primarily due to lower long-term service agreement expenses and a lower scope of work performed during plant outages in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic;
•a decrease of $15 million in nuclear generation expenses primarily due to lower nuclear labor costs, including contract labor, in part as a result of the COVID-19 pandemic; and
•higher nuclear insurance refunds of $7.8 million.

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

Other regulatory credits for the nine months ended September 30, 2020 included $35.8 million in amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. Other regulatory credits for the nine months ended September 30, 2019 included an additional provision of $11.5 million to reflect the current estimate of the historical year netting adjustment that was to be included in the 2019 formula
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rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing.

Income Taxes

The effective income tax rate was 26.2% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items. See Note 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 20.2% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 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 permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 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 discussion of the income tax deductions for stock-based compensation.

The effective income tax rates were 4.5% for the third quarter 2019 and (13.1%) for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were 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 Note 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.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion.  Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

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Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
 20202019
 (In Thousands)
Cash and cash equivalents at beginning of period$3,519 $119 
Cash flow provided by (used in):
Operating activities511,952 576,612 
Investing activities(634,739)(506,676)
Financing activities717,172 7,014 
Net increase in cash and cash equivalents594,385 76,950 
Cash and cash equivalents at end of period$597,904 $77,069 

Operating Activities

Net cash flow provided by operating activities decreased $64.7 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the timing of recovery of fuel and purchased power costs;
•an increase of $24.8 million in pension contributions in 2020. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding; and
•an increase of $22.8 million in spending on nuclear refueling outages in 2020.

The decrease was partially offset by:

•a decrease in the return of unprotected excess accumulated deferred income taxes to customers in 2020 as compared to the same period in 2019. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act; and
•$25 million in proceeds received from the DOE in 2020 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.

Investing Activities

Net cash flow used in investing activities increased $128.1 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•an increase of $71.2 million in storm spending;
•money pool activity;
•an increase of $38.1 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;
•an increase of $30.8 million in nuclear construction expenditures primarily as a result of work performed in 2020 on various ANO 2 outage projects;
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•an increase of $27 million in non-nuclear generation construction expenditures primarily due to increased spending on various projects in 2020; and
•an increase of $18.7 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Arkansas’s distribution system, including increased spending on advanced metering infrastructure.

The increase was partially offset by:

•$55 million in proceeds received from the DOE in 2020 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 spent nuclear fuel litigation; and
•a decrease of $44.1 million in transmission construction expenditures primarily due to a lower scope of work performed in 2020 as compared to 2019.

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 $51.7 million for the nine months ended September 30, 2020 compared to increasing by $6.9 million for the nine months ended September 30, 2019. 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 $710.2 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•issuances of $100 million of 4.00% Series mortgage bonds in March 2020 and $675 million of 2.65% Series mortgage bonds in September 2020;
•money pool activity;
•a decrease of $90 million in common equity distributions in 2020 in order to maintain Entergy Arkansas’s capital structure; and
•a decrease of $23.3 million in net long-term repayments in 2020 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility.

The increase was partially offset by the issuance of $350 million of 4.20% Series mortgage bonds in March 2019.

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 $21.6 million for the nine months ended September 30, 2020 compared to decreasing by $182.7 million for the nine months ended September 30, 2019.

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 increase in the debt to capital ratio is primarily due to the issuance of long-term debt in 2020.
September 30,
2020		December 31,
2019
Debt to capital56.2 %53.0 %
Effect of excluding the securitization bonds— %— %
Debt to capital, excluding securitization bonds (a)56.2 %53.0 %
Effect of subtracting cash(3.7 %)— %
Net debt to net capital, excluding securitization bonds (a)52.5 %53.0 %

(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, finance lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and 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 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 has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. Despite the effects of the pandemic on financial markets, Entergy Arkansas issued $100 million and $675 million of long-term mortgage bonds in March 2020 and September 2020, respectively, and renewed its short-term credit facility. Additional discussion of Entergy Arkansas’s liquidity and capital resources follows.

Entergy Arkansas is developing its capital investment plan for 2021 through 2023 and currently anticipates making $2.5 billion in capital investments during that period. The preliminary estimate includes specific investments such as the Searcy Solar Facility and Walnut Bend Solar Facility; 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.
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Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:
September 30,
2020		December 31,
2019		September 30,
2019		December 31,
2018
(In Thousands)
$51,697($21,634)$6,896($182,738)

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 September 2024. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 2021. 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 September 30, 2020, 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 September 30, 2020, a $3 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.

The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in September 2022.  As of September 30, 2020, $9.1 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.

Searcy Solar Facility

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the Searcy Solar Facility was in the public interest. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest, but declined to approve Entergy Arkansas’s preferred cost recovery rider mechanism, finding instead, based on the particular facts and circumstances presented, that the formula rate plan rider was a sufficient recovery mechanism for this resource.

Walnut Bend Solar Facility

In October 2020, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 100 MW Walnut Bend Solar Facility is in the public interest. Entergy Arkansas requested a decision by the APSC within 180 days of the filing and primarily requests cost recovery through the formula rate plan rider.

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.

Retail Rates

2020 Formula Rate Plan Filing

In July 2020, Entergy Arkansas filed with the APSC its 2020 formula rate plan filing to set its formula rate for the 2021 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2021, as amended through subsequent filings in the proceeding, and a netting adjustment for the historical year
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2019. Entergy Arkansas’s earned rate of return on common equity is 8.22% for the 2021 projected year and 9.07% for the 2019 historical year. The total revenue change is based upon a deficiency of approximately $64.3 million for the 2021 projected year and approximately $23.9 million for the 2019 historical year netting adjustment. The total proposed formula rate plan rider revenue change for 2021 is $88.2 million to produce a target rate of return of 9.75% for the projected year and the historical year. 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 $72.6 million. In October 2020 other parties in the proceeding filed their errors and objections recommending certain adjustments that would reduce the initially-proposed $74.3 million revenue requirement increase, and Entergy Arkansas filed responsive testimony disputing these adjustments. In October 2020, Entergy Arkansas filed with the APSC a unanimous settlement agreement reached with the other parties that resolved all but one issue. As a result of the settlement agreement, Entergy Arkansas’s requested revenue increase is $68.4 million, which is below the $72.6 million cap constraint. The remaining issue to be litigated concerns the methodology used to account for historical year revenues in the netting adjustment. Two parties have proposed a new methodology that, if adopted, effectively would reduce Entergy Arkansas’s request to $0.9 million for the 2021 projected year. This remaining issue will go to hearing in November 2020 and a final decision by the APSC is expected in December 2020. Also with the formula rate plan filing, Entergy Arkansas is requesting an extension of the formula rate plan rider for a second five-year term. A decision by the APSC on the extension is requested before February 2021.

Energy Cost Recovery Rider

In March 2020, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01462 per kWh to $0.01052 per kWh. The redetermined rate became effective with the first billing cycle in April 2020 through the normal operation of the tariff.

Opportunity Sales Proceeding

As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit by Entergy, the LPSC, and the APSC. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument is scheduled for December 2020.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In November 2019 the FERC issued an order denying the LPSC’s complaint. The order concluded that the settlement agreement approved by the FERC in December 2015 terminating the System Agreement barred the LPSC’s new complaint. In December 2019 the LPSC requested rehearing of the FERC’s November 2019 order, and in July 2020 the FERC issued an order dismissing the LPSC’s request for rehearing. In September 2020 the LPSC appealed the FERC’s orders dismissing the new opportunity sales complaint to the D.C. Circuit.

Also as discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application with the APSC requesting approval of a special rider tariff to recover the costs of its opportunity sales payments from its retail customers over a 24-month period. In January 2020 the Attorney General and Arkansas Electric Energy Consumers, Inc. filed testimony opposing the recovery by Entergy Arkansas of the opportunity sales payment but also claiming that certain components of the payment should be segregated and refunded to customers. In March 2020, Entergy Arkansas filed rebuttal testimony.

In July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. The order also directs Entergy Arkansas to refund to its retail customers within 30 days of the order the FERC-determined over-collection of $13.7 million, plus interest, associated with a recalculated bandwidth remedy.
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In addition to these primary findings, the order also denied the Attorney General’s request for Entergy Arkansas to prepare a compliance filing detailing all of the retail impacts from the opportunity sales and denied a request by the Arkansas Electric Energy Consumers to recalculate all costs using the revised responsibility ratio. Entergy Arkansas filed a motion for temporary stay of the 30-day requirement to allow Entergy Arkansas a reasonable opportunity to seek rehearing of the APSC order, but in July 2020 the APSC denied Entergy Arkansas’s request for a stay and directed Entergy Arkansas to refund to its retail ratepayers the component of the total FERC-determined opportunity sales payment that was associated with increased bandwidth remedy payments of $13.7 million, plus interest. The refunds were issued in the August 2020 billing cycle. While the APSC denied Entergy Arkansas’s stay request, Entergy Arkansas believes its actions were prudent and, therefore, the costs, including the $13.7 million, plus interest, are recoverable. In July 2020, Entergy Arkansas requested rehearing of the APSC order, which rehearing was denied by the APSC in August 2020. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. Entergy Arkansas expects to file a response opposing the APSC’s motion.

Net Metering Legislation

As discussed in the Form 10-K, an Arkansas law was enacted effective July 2019 that, among other things, expands the definition of a “net metering customer” to include two additional types of customers: (1) customers that lease net metering facilities, subject to certain leasing arrangements, and (2) government entities or other entities exempt from state and federal income taxes that enter into a service contract for a net metering facility. The latter provision would allow eligible entities, many of whom are small and large general service customers, to purchase renewable energy directly from third party providers and receive bill credits for these purchases. The APSC was given authority under this law to address certain matters, such as cost shifting and the appropriate compensation for net metered energy, and has initiated proceedings for this purpose. The APSC issued an order in June 2020, and in July 2020 several parties, including Entergy Arkansas, filed for rehearing on multiple grounds, including for the reasons that it imposes an unreasonable rate structure and allows facilities to net meter that do not meet the statutory definition of net metering facilities. After granting the rehearing requests, the APSC issued an order in September 2020 largely upholding its June 2020 order. In October 2020, Entergy Arkansas filed for rehearing of the APSC’s September 2020 order.

COVID-19 Orders

In April 2020, in light of the COVID-19 pandemic, the APSC issued an order requiring utilities, to the extent they had not already done so, to suspend service disconnections during the remaining pendency of the Arkansas Governor’s emergency declaration or until the APSC rescinds the directive. The order also authorizes utilities to establish a regulatory asset to record costs resulting from the suspension of service disconnections, directs that in future proceedings the APSC will consider whether the request for recovery of these regulatory assets is reasonable and necessary, and requires utilities to track and report the costs and any savings directly attributable to suspension of disconnects. In May 2020 the APSC approved Entergy Arkansas expanding delayed payment arrangements to assist customers during the pandemic. Quarterly reporting began in August 2020 and the APSC ordered additional reporting in October 2020 regarding utilities’ transitional plans for ending the moratorium on service disconnects. As of September 30, 2020, Entergy Arkansas recorded a regulatory asset of $6.1 million for costs associated with the COVID-19 pandemic.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

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Entergy Arkansas, 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 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 Arkansas’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. The following is an update to that discussion.

Other Postretirement Benefits
As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, Entergy Arkansas now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $10.1 million.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$644,389 $687,526 $1,618,068 $1,776,267 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale77,239 109,779 217,342 370,534 
Purchased power57,599 61,074 145,811 156,417 
Nuclear refueling outage expenses13,010 17,381 42,809 51,823 
Other operation and maintenance169,898 188,299 486,525 542,765 
Decommissioning18,449 17,422 54,596 50,351 
Taxes other than income taxes34,379 31,783 92,611 87,327 
Depreciation and amortization84,515 78,594 252,574 231,502 
Other regulatory charges (credits) - net(28,348)1,018 (67,632)(8,873)
TOTAL426,741 505,350 1,224,636 1,481,846 
OPERATING INCOME217,648 182,176 393,432 294,421 
OTHER INCOME
Allowance for equity funds used during construction3,876 3,977 10,671 10,777 
Interest and investment income2,218 8,788 18,402 19,193 
Miscellaneous - net(4,465)(4,286)(17,034)(12,704)
TOTAL1,629 8,479 12,039 17,266 
INTEREST EXPENSE
Interest expense36,902 35,454 108,494 104,664 
Allowance for borrowed funds used during construction(1,702)(1,641)(4,686)(4,384)
TOTAL35,200 33,813 103,808 100,280 
INCOME BEFORE INCOME TAXES184,077 156,842 301,663 211,407 
Income taxes48,234 7,126 61,055 (27,729)
NET INCOME$135,843 $149,716 $240,608 $239,136 
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$240,608 $239,136 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization366,549 351,390 
Deferred income taxes, investment tax credits, and non-current taxes accrued79,948 85,246 
Changes in assets and liabilities:
Receivables(73,890)(70,395)
Fuel inventory4,761 (5,350)
Accounts payable(26,547)(24,766)
Taxes accrued(10,733)(18,608)
Interest accrued18,125 20,206 
Deferred fuel costs3,203 52,468 
Other working capital accounts(9,027)44,803 
Provisions for estimated losses3,508 8,841 
Other regulatory assets(50,262)(55,749)
Other regulatory liabilities(484)32,537 
Pension and other postretirement liabilities(31,245)(26,136)
Other assets and liabilities(2,562)(57,011)
Net cash flow provided by operating activities511,952 576,612 
INVESTING ACTIVITIES
Construction expenditures(593,249)(488,487)
Allowance for equity funds used during construction10,671 11,016 
Payment for purchase of assets(5,988)— 
Nuclear fuel purchases(72,601)(26,732)
Proceeds from sale of nuclear fuel30,638 22,834 
Proceeds from nuclear decommissioning trust fund sales254,847 199,031 
Investment in nuclear decommissioning trust funds(266,397)(214,205)
Change in money pool receivable - net(51,697)(6,896)
Changes in securitization account4,036 (3,238)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs55,001 — 
Change in other investments — 1 
Net cash flow used in investing activities(634,739)(506,676)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,058,977 781,510 
Retirement of long-term debt(298,071)(473,827)
Changes in money pool payable - net(21,634)(182,738)
Common equity distributions paid(25,000)(115,000)
Other2,900 (2,931)
Net cash flow provided by financing activities717,172 7,014 
Net increase in cash and cash equivalents594,385 76,950 
Cash and cash equivalents at beginning of period3,519 119 
Cash and cash equivalents at end of period$597,904 $77,069 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: 
Cash paid during the period for:
Interest - net of amount capitalized$86,906 $80,644 
See Notes to Financial Statements.
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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$121 $3,519 
Temporary cash investments597,783 — 
Total cash and cash equivalents597,904 3,519 
Securitization recovery trust account— 4,036 
Accounts receivable:
Customer198,901 117,679 
Allowance for doubtful accounts(12,229)(1,169)
Associated companies101,064 29,178 
Other41,481 117,653 
Accrued unbilled revenues113,199 108,489 
Total accounts receivable442,416 371,830 
Fuel inventory - at average cost28,984 33,745 
Materials and supplies - at average cost227,784 211,320 
Deferred nuclear refueling outage costs44,576 48,875 
Prepayments and other18,308 14,096 
TOTAL1,359,972 687,421 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,168,806 1,101,283 
Other342 345 
TOTAL1,169,148 1,101,628 
UTILITY PLANT
Electric12,650,481 12,293,483 
Construction work in progress337,458 197,775 
Nuclear fuel146,150 195,547 
TOTAL UTILITY PLANT13,134,089 12,686,805 
Less - accumulated depreciation and amortization5,205,764 5,019,826 
UTILITY PLANT - NET7,928,325 7,666,979 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $— as of September 30, 2020 and $1,706 as of December 31, 2019)
1,717,112 1,666,850 
Deferred fuel costs68,087 67,690 
Other18,013 15,065 
TOTAL1,803,212 1,749,605 
TOTAL ASSETS$12,260,657 $11,205,633 
See Notes to Financial Statements.
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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$485,000 $— 
Accounts payable:
Associated companies56,535 111,785 
Other185,221 202,201 
Customer deposits100,933 101,411 
Taxes accrued71,098 81,831 
Interest accrued40,913 22,788 
Deferred fuel costs57,321 53,721 
Current portion of unprotected excess accumulated deferred income taxes— 9,296 
Other47,308 38,760 
TOTAL1,044,329 621,793 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued1,279,679 1,183,126 
Accumulated deferred investment tax credits30,800 31,701 
Regulatory liability for income taxes - net465,204 478,174 
Other regulatory liabilities581,337 559,555 
Decommissioning1,295,437 1,242,616 
Accumulated provisions67,388 63,880 
Pension and other postretirement liabilities287,808 319,075 
Long-term debt (includes securitization bonds of $— as of September 30, 2020 and $6,772 as of December 31, 2019)
3,795,229 3,517,208 
Other71,901 62,568 
TOTAL7,874,783 7,457,903 
Commitments and Contingencies
EQUITY
Member's equity3,341,545 3,125,937 
TOTAL3,341,545 3,125,937 
TOTAL LIABILITIES AND EQUITY$12,260,657 $11,205,633 
See Notes to Financial Statements.
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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Member's Equity
(In Thousands)
Balance at December 31, 2018$2,983,103 
Net income39,121 
Balance at March 31, 20193,022,224 
Net income50,299 
Common equity distributions(115,000)
Balance at June 30, 20192,957,523 
Net income149,716 
Balance at September 30, 2019$3,107,239 
Balance at December 31, 2019$3,125,937 
Net income44,595 
Balance at March 31, 20203,170,532 
Net income60,170 
Balance at June 30, 20203,230,702 
Net income135,843 
Common equity distributions(25,000)
Balance at September 30, 2020$3,341,545 
See Notes to Financial Statements.
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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$274 $254 $20 8 
Commercial138 163 (25)(15)
Industrial138 156 (18)(12)
Governmental5 6 (1)(17)
Total billed retail555 579 (24)(4)
Sales for resale:
Associated companies29 30 (1)(3)
Non-associated companies35 29 6 21 
Other25 50 (25)(50)
Total$644 $688 ($44)(6)
Billed Electric Energy Sales (GWh):
Residential2,380 2,393 (13)(1)
Commercial1,619 1,761 (142)(8)
Industrial2,056 2,125 (69)(3)
Governmental63 67 (4)(6)
Total retail6,118 6,346 (228)(4)
Sales for resale:
Associated companies520 588 (68)(12)
Non-associated companies1,494 1,515 (21)(1)
Total8,132 8,449 (317)(4)
Nine Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$665 $621 $44 7 
Commercial355 413 (58)(14)
Industrial345 396 (51)(13)
Governmental14 16 (2)(13)
Total billed retail1,379 1,446 (67)(5)
Sales for resale:
Associated companies81 89 (8)(9)
Non-associated companies62 124 (62)(50)
Other96 117 (21)(18)
Total$1,618 $1,776 ($158)(9)
Billed Electric Energy Sales (GWh):
Residential5,951 6,144 (193)(3)
Commercial4,079 4,433 (354)(8)
Industrial5,605 5,800 (195)(3)
Governmental169 181 (12)(7)
Total retail15,804 16,558 (754)(5)
Sales for resale:
Associated companies1,232 1,694 (462)(27)
Non-associated companies3,471 6,071 (2,600)(43)
Total20,507 24,323 (3,816)(16)
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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of the COVID-19 pandemic.

Hurricane Laura

In August 2020, Hurricane Laura caused extensive damage to Entergy Louisiana’s service area. The storm resulted in widespread power outages and significant damage primarily to distribution and transmission infrastructure and large portions of the underlying transmission system required nearly a complete rebuild. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Laura are currently estimated to be in the range of $1.25 billion to $1.4 billion. Entergy Louisiana also expects revenues in 2020 to be adversely affected, primarily due to power outages resulting from the hurricane. Entergy Louisiana is considering all reasonable avenues to recover storm-related costs from Hurricane Laura, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Entergy Louisiana has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy Louisiana recorded corresponding regulatory assets of approximately $155 million and construction work in progress of approximately $1.095 billion. Entergy Louisiana recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy Louisiana has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy Louisiana is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

Hurricane Delta

In October 2020, Hurricane Delta caused significant damage to Entergy Louisiana’s service area. The storm resulted in widespread power outages, significant damage primarily to distribution infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities in areas with damage from Hurricane Delta are currently estimated to be in the range of $180 million to $205 million. Entergy Louisiana is considering all available avenues to recover storm-related costs from Hurricane Delta, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to portions of Entergy's service area in Louisiana, including New Orleans. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Entergy is still assessing and developing an estimate of the total restoration costs for the repair and/or replacement of the infrastructure damaged by Hurricane Zeta. Entergy is considering all available avenues to recover storm-related costs from Hurricane Zeta, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

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Management's Financial Discussion and Analysis
Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income decreased $31.8 million primarily due to lower volume/weather, lower other income, higher taxes other than income taxes, and higher interest expense, partially offset by higher retail electric price and lower other operation and maintenance expenses.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income increased $17.3 million primarily due to the $58 million reduction in income tax expense resulting from an IRS settlement in the first quarter 2020 related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing, which also resulted in a $29 million ($21 million net-of-tax) regulatory charge to reflect Entergy Louisiana’s agreement to share the savings with customers. Also contributing to the increase was higher retail electric price and lower other operation and maintenance expenses. The increase was partially offset by lower volume/weather, lower other income, higher interest expense, and higher taxes other than income taxes. See Note 10 to the financial statements herein for further discussion of the tax settlement.

Operating Revenues

Third Quarter 2020 Compared to Third Quarter 2019

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$1,231.7 
Fuel, rider, and other revenues that do not significantly affect net income(146.8)
Volume/weather(20.6)
Return of unprotected excess accumulated deferred income taxes to customers9.4 
Retail electric price46.3 
2020 operating revenues$1,120.0 

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to decreased commercial and industrial usage as a result of the COVID-19 pandemic and the effects of Hurricane Laura. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. Entergy Louisiana continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. See “Hurricane Laura” above for discussion of Hurricane Laura.

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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. In third quarter 2020, $7.8 million was returned to customers as compared to $17.2 million in third quarter 2019. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements 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 an interim increase in formula rate plan revenues effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station and increases in formula rate plan revenues effective September 2019 and September 2020. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$3,297.3 
Fuel, rider, and other revenues that do not significantly affect net income(318.8)
Volume/weather(47.3)
Return of unprotected excess accumulated deferred income taxes to customers7.4 
Retail electric price123.7 
2020 operating revenues$3,062.3 

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to decreased commercial and industrial usage as a result of the COVID-19 pandemic and the effects of Hurricane Laura and the effect of less favorable weather on residential sales, partially offset by increased residential usage as a result of the COVID-19 pandemic offset by the effects of Hurricane Laura. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. Entergy Louisiana continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. See “Hurricane Laura” above for discussion of Hurricane Laura.

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. In the nine months ended September 30, 2020, $23.4 million was returned to customers as compared to $30.8 million in the nine months ended September 30, 2019. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements 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 interim increases in formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for the J. Wayne Leonard Power Station
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Management's Financial Discussion and Analysis
(formerly St. Charles Power Station) and effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station and increases in formula rate plan revenues effective September 2019 and September 2020. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

Other Income Statement Variances

Third Quarter 2020 Compared to Third Quarter 2019

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $6.8 million in loss provisions; and
•a decrease of $3.6 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services.

The decrease was partially offset by:

•an increase of $3.5 million in nuclear generation expenses primarily due to the effects of recording in third quarter 2019 the final judgment to resolve claims in the River Bend damages case against the DOE related to spent nuclear fuel storage costs. The damages award included the reimbursement of $5.2 million of spent nuclear fuel storage costs that were previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for further discussion of the spent nuclear fuel litigation; and
•an increase of $2.6 million in compensation and benefits costs primarily due to an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes resulting from a millage increase and a change in estimated property assessments.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station, which was placed in service in March 2020.

Other income decreased primarily due to changes in decommissioning trust fund activity and a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the Lake Charles Power Station project.

Interest expense increased primarily due to the issuances of $300 million of 4.20% Series mortgage bonds and $350 million of 2.90% Series mortgage bonds, each in March 2020, and a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2019, including the Lake Charles Power Station project.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $13.7 million in nuclear generation expenses primarily due to a lower scope of work performed in 2020 as compared to 2019, in part as a result of the COVID-19 pandemic;
•a decrease of $10.9 million in non-nuclear generation expenses primarily due to a lower scope of work
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Management's Financial Discussion and Analysis
performed during plant outages in 2020 as compared to the same period in 2019, partially offset by increases resulting from the J. Wayne Leonard Power Station (formerly St. Charles Power Station) and the Lake Charles Power Station being placed in service;
•a decrease of $8.5 million in loss provisions; and
•a decrease of $8.3 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services.

The decrease was partially offset by an increase of $8.1 million in compensation and benefits costs primarily due to an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes resulting from a millage increase and a change in estimated property assessments.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the J. Wayne Leonard Power Station (formerly St. Charles Power Station), which was placed in service in May 2019 and the Lake Charles Power Station, which was placed in service in March 2020.

Other income decreased primarily due to:

•a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the J. Wayne Leonard Power Station (formerly St. Charles Power Station) and the Lake Charles Power Station projects; and
•changes in decommissioning trust fund activity.

Other regulatory credits include regulatory charges of $29 million recorded in first quarter 2020 due to a settlement with the IRS related to the uncertain tax position regarding Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 10 to the financial statements herein for further discussion of the settlement and savings obligation.

Interest expense increased primarily due to:

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2019, including the J. Wayne Leonard Power Station (formerly St. Charles Power Station) and Lake Charles Power Station projects;
•the issuance of $525 million of 4.20% Series mortgage bonds in March 2019; and
•the issuances of $300 million of 4.20% Series mortgage bonds and $350 million of 2.90% Series mortgage bonds, each in March 2020.

Income Taxes

The effective income tax rate was 18.1% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 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.

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The effective income tax rate was 5.7% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based compensation, the amortization of excess accumulated deferred income taxes, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein for discussion of the IRS settlement. See Note 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 discussion of the income tax deductions for stock-based compensation.

The effective income tax rates were 17.7% for the third quarter 2019 and 16.3% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes, 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. See Note 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.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Cash and cash equivalents at beginning of period$2,006 $43,364 
Cash flow provided by (used in):
    Operating activities1,113,574 962,443 
    Investing activities(1,096,819)(1,260,023)
    Financing activities233,402 382,261 
Net increase in cash and cash equivalents250,157 84,681 
Cash and cash equivalents at end of period$252,163 $128,045 


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Operating Activities

Net cash flow provided by operating activities increased $151.1 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the timing of payments to vendors;
•a decrease of $61.2 million in spending on nuclear refueling outages;
•income tax refunds of $20.7 million in 2020. Entergy Louisiana had income tax receipts in 2020 as a result of a refund of an overpayment on a prior year state income tax return; and
•$28.1 million in proceeds received from the DOE in June 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed, compared to $16.6 million received in September 2019. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

The increase was partially offset by:

•the timing of collection of receivables from customers, in part due to the COVID-19 pandemic;
•the timing of recovery of fuel and purchased power costs;
•an increase of $27.1 million in interest payments; and
•an increase of $12.7 million in pension contributions in 2020. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

Investing Activities

Net cash flow used in investing activities decreased $163.2 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•a decrease of $174.6 million in non-nuclear generation construction expenditures due to higher spending in 2019 on the Lake Charles Power Station and J. Wayne Leonard Power Station (formerly St. Charles Power Station) projects;
•a decrease of $97.4 million in nuclear construction expenditures primarily due to decreased spending on various projects in 2020;
•a decrease of $68.5 million in transmission construction expenditures primarily due to a higher scope of work performed in 2020 as compared to 2019;
•an increase of $44.1 million in net receipts from storm reserve escrow accounts; and
•a decrease of $10.2 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.

The decrease was partially offset by:

•an increase of $80.7 million in storm spending in 2020, primarily due to Hurricane Laura restoration efforts;
•money pool activity; and
•an increase of $41.3 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Louisiana’s distribution system, including increased spending on advanced metering infrastructure.

Increases in Entergy Louisiana’s receivable from the money pool are a use of cash flow, and Entergy Louisiana’s receivable from the money pool increased by $21.6 million for the nine months ended September 30, 2020 compared to decreasing by $35.5 million for the nine months ended September 30, 2019. The money pool is
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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 $148.9 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the issuance of $525 million of 4.20% Series mortgage bonds in March 2019;
•the repayment of $250 million of 3.95% Series mortgage bonds due October 2020;
•money pool activity; and
•net repayments of long-term borrowings of $37.9 million in 2020 compared to net long-term borrowings of $29.2 million in 2019 on the nuclear fuel company variable interest entities’ credit facilities.

The decrease was partially offset by the issuances of $350 million of 2.90% Series mortgage bonds and $300 million of 4.20% Series mortgage bonds, each in March 2020, and a decrease of $133.5 million in common equity distributions in 2020 primarily due to upcoming capital expenditures.

Decreases in Entergy Louisiana’s payable to the money pool are a use of cash flow, and Entergy Louisiana’s payable to the money pool decreased by $82.8 million for the nine months ended September 30, 2020.

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.
September 30,
2020		December 31,
2019
Debt to capital52.4 %53.4 %
Effect of excluding securitization bonds(0.1 %)(0.1 %)
Debt to capital, excluding securitization bonds (a)52.3 %53.3 %
Effect of subtracting cash(0.8 %)(0.1 %)
Net debt to net capital, excluding securitization bonds (a)51.5 %53.2 %

(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, finance lease obligations, 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 has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. Despite the effects of the pandemic on financial markets Entergy Louisiana issued $650 million of long-term mortgage bonds in March 2020. Additional discussion of Entergy Louisiana’s liquidity and capital resources follows.

Entergy Louisiana is developing its capital investment plan for 2021 through 2023 and currently anticipates making $4.6 billion in capital investments during that period. The preliminary estimate includes specific investments such as transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to maintain 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.

Entergy Louisiana’s receivables from or (payables to) the money pool were as follows:
September 30,
2020		December 31,
2019		September 30,
2019		December 31,
2018
(In Thousands)
$21,649($82,826)$11,358$46,843

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 September 2024.  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 September 30, 2020, there were no cash borrowings and 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 September 30, 2020, $21.2 million in letters of credit were 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, each in the amount of $105 million and scheduled to expire in September 2022.  As of September 30, 2020, $30.9 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of September 30, 2020, $51.4 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.

Entergy Louisiana has $257 million in its storm reserve escrow account at September 30, 2020.

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Lake Charles Power Station

As discussed in the Form 10-K, the LPSC issued an order in July 2017 approving certification that the public necessity and convenience would be served by the construction of the Lake Charles Power Station. The plant commenced commercial operation in March 2020.

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.

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. In June 2020, Entergy Louisiana submitted information to the LPSC to review the prudence of Entergy Louisiana’s management of the project. In August 2020 discovery commenced and a procedural schedule was established with a hearing in July 2021.

2018 Formula Rate Plan Filing

Commercial operation at Lake Charles Power Station commenced in March 2020. In March 2020, Entergy Louisiana filed an update to its 2018 formula rate plan evaluation report to include the estimated first-year revenue requirement of $108 million associated with the Lake Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of April 2020.

2019 Formula Rate Plan Filing

In May 2020, Entergy Louisiana filed with the LPSC its formula rate plan evaluation report for its 2019 calendar year operations. The 2019 test year evaluation report produced an earned return on common equity of 9.66%. As such, no change to base rider formula rate plan revenue is required. Although base rider formula rate plan revenue will not change as a result of this filing, overall formula rate plan revenues will increase by approximately $103 million. This outcome is driven by the removal of prior year credits associated with the sale of the Willow Glen Power Station and an increase in the transmission recovery mechanism. Also contributing to the overall change is an increase in legacy formula rate plan revenue requirements driven by legacy Entergy Louisiana capacity cost true-ups and higher annualized legacy Entergy Gulf States Louisiana revenues due to higher billing determinants, offset by reductions in MISO cost recovery mechanism and tax reform adjustment mechanism revenue requirements. In August 2020 the LPSC staff submitted a list of items for which it needs additional information to confirm the accuracy and compliance of the 2019 test year evaluation report. The LPSC staff objected to a proposed revenue neutral adjustment regarding a certain rider as being beyond the scope of permitted formula rate plan adjustments. Rates reflected in the May 2020 filing, with the exception of the revenue neutral rider adjustment, and as updated in an August 2020 filing, were implemented in September 2020, subject to refund. Entergy Louisiana is in the process of providing additional information and details on the May 2020 filing as requested by the LPSC staff.

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Request for Extension and Modification of Formula Rate Plan

In May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. In its application, Entergy Louisiana seeks to maintain a 9.8% return on equity, with a bandwidth of 60 basis points above and below the midpoint, with a first-year midpoint reset. Entergy Louisiana also seeks to maintain its existing additional capacity mechanism, tax reform adjustment mechanism, transmission recovery mechanism, and the MISO cost recovery mechanism. Entergy Louisiana also seeks to add a distribution cost recovery mechanism which operates in substantially the same manner as the transmission recovery mechanism, seeks to utilize end of period rate base to calculate cost of service, and requests a deferral of certain expenses incurred for outside of right-of-way vegetation programs.

Retail Rates - Gas

2017 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2018 Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. 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. In October 2019 the LPSC staff issued its report finding that Entergy Louisiana’s filing complied with the terms of the rate stabilization plan but recommending an additional refund of $0.7 million related to the Tax Act. In June 2020, the LPSC approved a joint report acknowledging Entergy Louisiana’s prior refunds and offsets for flood recovery costs, and required a further refund of $0.8 million, inclusive of carrying costs.

2018 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2019 Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. The filing of the evaluation report for the test year 2018 reflected an earned return on common equity of 2.69%. This earned return is below the earning sharing band of the gas rate stabilization plan and results in a rate increase of $2.8 million. Rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. In August 2020 the LPSC staff filed its report concurring with Entergy Louisiana’s calculation that the gas rate stabilization plan required a rate increase of $2.8 million. The LPSC accepted the staff’s report at its September 2020 meeting.

Fuel and purchased power recovery

In March 2020 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2016 through 2019. Discovery commenced in September 2020.

COVID-19 Orders

In April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. While the suspension of late fees and disconnects for non-pay was only extended until the first billing cycle after July 16, 2020, Entergy Louisiana has not yet resumed disconnections and continues to defer the associated costs. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of September 30, 2020, Entergy Louisiana recorded a regulatory asset of $27.4 million for costs associated with the COVID-19 pandemic.
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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.

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, 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.

Other Postretirement Benefits
As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, Entergy Louisiana now expects 2020 other postretirement health care and life insurance benefit cost, including amounts capitalized, of $5.6 million.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.
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CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$1,110,217 $1,221,874 $3,024,359 $3,252,826 
Natural gas9,805 9,803 37,962 44,498 
TOTAL1,120,022 1,231,677 3,062,321 3,297,324 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale162,981 259,419 469,083 627,240 
Purchased power160,069 197,830 474,598 678,150 
Nuclear refueling outage expenses13,796 14,026 41,080 40,225 
Other operation and maintenance244,136 249,773 693,010 726,496 
Decommissioning16,407 15,606 48,611 43,544 
Taxes other than income taxes61,797 49,602 160,592 145,942 
Depreciation and amortization154,162 137,891 453,552 394,271 
Other regulatory credits - net(17,822)(29,224)(25,892)(90,762)
TOTAL795,526 894,923 2,314,634 2,565,106 
OPERATING INCOME324,496 336,754 747,687 732,218 
OTHER INCOME
Allowance for equity funds used during construction6,255 14,609 27,197 59,194 
Interest and investment income61,487 45,237 135,625 166,721 
Miscellaneous - net(40,025)(15,067)(57,235)(79,717)
TOTAL27,717 44,779 105,587 146,198 
INTEREST EXPENSE
Interest expense82,716 78,350 248,529 230,684 
Allowance for borrowed funds used during construction(3,256)(7,041)(13,590)(28,145)
TOTAL79,460 71,309 234,939 202,539 
INCOME BEFORE INCOME TAXES272,753 310,224 618,335 675,877 
Income taxes49,287 54,964 35,014 109,900 
NET INCOME$223,466 $255,260 $583,321 $565,977 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
Net Income$223,466 $255,260 $583,321 $565,977 
Other comprehensive income (loss)
Pension and other postretirement liabilities (net of tax expense (benefit) of ($282), ($342), $2,724, and ($1,026))
(800)(969)7,722 (2,907)
Other comprehensive income (loss)(800)(969)7,722 (2,907)
Comprehensive Income$222,666 $254,291 $591,043 $563,070 
See Notes to Financial Statements.



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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$583,321 $565,977 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization591,045 498,397 
Deferred income taxes, investment tax credits, and non-current taxes accrued56,767 174,825 
Changes in working capital:
Receivables(100,718)(72,018)
Fuel inventory(3,845)(1,752)
Accounts payable169,577 (40,131)
Prepaid taxes and taxes accrued148,379 78,910 
Interest accrued(4,220)5,102 
Deferred fuel costs(61,732)(11,459)
Other working capital accounts(33,691)(62,332)
Changes in provisions for estimated losses(42,624)9,748 
Changes in other regulatory assets(129,843)(103,635)
Changes in other regulatory liabilities(19,761)(26,115)
Changes in pension and other postretirement liabilities(49,168)(15,761)
Other10,087 (37,313)
Net cash flow provided by operating activities1,113,574 962,443 
INVESTING ACTIVITIES
Construction expenditures(1,064,765)(1,277,108)
Allowance for equity funds used during construction27,197 59,194 
Payment for purchase of assets(14,511)— 
Nuclear fuel purchases(76,392)(63,157)
Proceeds from the sale of nuclear fuel35,041 11,608 
Receipts from storm reserve escrow account40,601 — 
Payments to storm reserve escrow account(1,467)(5,013)
Changes to securitization account(5,925)(6,467)
Proceeds from nuclear decommissioning trust fund sales281,131 307,164 
Investment in nuclear decommissioning trust funds(301,170)(331,138)
Changes in money pool receivable - net(21,649)35,485 
Insurance proceeds— 7,040 
Litigation proceeds for reimbursement of spent nuclear fuel storage costs5,090 — 
Other— 2,369 
Net cash flow used in investing activities(1,096,819)(1,260,023)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,800,392 2,332,003 
Retirement of long-term debt(1,453,564)(1,798,014)
Change in money pool payable - net(82,826)— 
Distributions paid:
Common equity distributions paid(21,500)(155,000)
Other(9,100)3,272 
Net cash flow provided by financing activities233,402 382,261 
Net increase in cash and cash equivalents250,157 84,681 
Cash and cash equivalents at beginning of period2,006 43,364 
Cash and cash equivalents at end of period$252,163 $128,045 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$246,456 $219,323 
Income taxes($20,684)$— 
See Notes to Financial Statements.
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CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$347 $488 
Temporary cash investments251,816 1,518 
Total cash and cash equivalents252,163 2,006 
Accounts receivable:
Customer306,768 194,869 
Allowance for doubtful accounts(27,157)(1,902)
Associated companies91,987 77,212 
Other40,667 42,179 
Accrued unbilled revenues191,661 169,201 
Total accounts receivable603,926 481,559 
Deferred fuel costs6,087 — 
Fuel inventory45,458 41,613 
Materials and supplies - at average cost411,923 354,020 
Deferred nuclear refueling outage costs31,643 56,743 
Prepaid taxes— 7,959 
Prepayments and other48,537 37,837 
TOTAL1,399,737 981,737 
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests1,390,587 1,390,587 
Decommissioning trust funds1,650,425 1,563,812 
Storm reserve escrow account256,740 295,875 
Non-utility property - at cost (less accumulated depreciation)320,815 312,896 
Other13,267 13,476 
TOTAL3,631,834 3,576,646 
UTILITY PLANT
Electric23,986,044 22,620,365 
Natural gas247,328 235,678 
Construction work in progress1,800,139 1,383,603 
Nuclear fuel220,704 267,779 
TOTAL UTILITY PLANT26,254,215 24,507,425 
Less - accumulated depreciation and amortization9,314,920 9,118,524 
UTILITY PLANT - NET16,939,295 15,388,901 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $10,498 as of September 30, 2020 and $27,596 as of December 31, 2019)
1,445,054 1,315,211 
Deferred fuel costs168,122 168,122 
Other31,440 33,491 
TOTAL1,644,616 1,516,824 
TOTAL ASSETS$23,615,482 $21,464,108 
See Notes to Financial Statements.
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CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$240,000 $320,002 
Accounts payable:
Associated companies115,926 187,615 
Other1,679,785 357,206 
Customer deposits154,566 153,097 
Taxes accrued140,420 — 
Interest accrued83,524 87,744 
Deferred fuel costs— 55,645 
Current portion of unprotected excess accumulated deferred income taxes31,138 31,138 
Other66,510 64,668 
TOTAL2,511,869 1,257,115 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued2,549,035 2,464,513 
Accumulated deferred investment tax credits108,520 112,128 
Regulatory liability for income taxes - net460,482 500,083 
Other regulatory liabilities813,980 794,140 
Decommissioning1,553,957 1,497,349 
Accumulated provisions277,795 320,419 
Pension and other postretirement liabilities629,990 677,619 
Long-term debt (includes securitization bonds of $22,676 as of September 30, 2020 and $33,220 as of December 31, 2019)
7,411,976 6,983,667 
Other331,248 459,957 
TOTAL14,136,983 13,809,875 
Commitments and Contingencies
EQUITY
Member's equity6,954,346 6,392,556 
Accumulated other comprehensive income12,284 4,562 
TOTAL6,966,630 6,397,118 
TOTAL LIABILITIES AND EQUITY$23,615,482 $21,464,108 
See Notes to Financial Statements.
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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Common Equity
Member’s
Equity		Accumulated
Other
Comprehensive
Loss		Total
(In Thousands)
Balance at December 31, 2018$5,909,071 ($6,153)$5,902,918 
Net income127,633 — 127,633 
Other comprehensive loss— (969)(969)
Distributions declared on common equity(49,000)— (49,000)
Other(11)— (11)
Balance at March 31, 20195,987,693 (7,122)5,980,571 
Net income183,084 — 183,084 
Other comprehensive loss— (969)(969)
Distributions declared on common equity(53,000)— (53,000)
Other(14)— (14)
Balance at June 30, 20196,117,763 (8,091)6,109,672 
Net income255,260 — 255,260 
Other comprehensive loss— (969)(969)
Distributions declared on common equity(53,000)— (53,000)
Other(8)— (8)
Balance at September 30, 2019$6,320,015 ($9,060)$6,310,955 
Balance at December 31, 2019$6,392,556 $4,562 $6,397,118 
Net income189,396 — 189,396 
Other comprehensive income— 9,467 9,467 
Distributions declared on common equity(11,500)— (11,500)
Other(10)— (10)
Balance at March 31, 20206,570,442 14,029 6,584,471 
Net income170,459 — 170,459 
Other comprehensive loss— (945)(945)
Distributions declared on common equity(5,000)— (5,000)
Other(13)— (13)
Balance at June 30, 20206,735,888 13,084 6,748,972 
Net income223,466 — 223,466 
Other comprehensive loss— (800)(800)
Distributions declared on common equity(5,000)— (5,000)
Other(8)— (8)
Balance at September 30, 2020$6,954,346 $12,284 $6,966,630 
See Notes to Financial Statements.
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SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$413 $426 ($13)(3)
Commercial248 277 (29)(10)
Industrial317 376 (59)(16)
Governmental18 19 (1)(5)
Total billed retail996 1,098 (102)(9)
Sales for resale:
Associated companies65 66 (1)(2)
Non-associated companies17 16 1 6 
Other32 42 (10)(24)
Total$1,110 $1,222 ($112)(9)
Billed Electric Energy Sales (GWh):
Residential4,557 4,614 (57)(1)
Commercial3,033 3,325 (292)(9)
Industrial7,129 7,741 (612)(8)
Governmental202 215 (13)(6)
Total retail14,921 15,895 (974)(6)
Sales for resale:
Associated companies1,477 1,494 (17)(1)
Non-associated companies630 526 104 20 
Total17,028 17,915 (887)(5)
Nine Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$974 $980 ($6)(1)
Commercial660 716 (56)(8)
Industrial974 1,108 (134)(12)
Governmental51 54 (3)(6)
Total billed retail2,659 2,858 (199)(7)
Sales for resale:
Associated companies201 201 — — 
Non-associated companies42 48 (6)(13)
Other122 146 (24)(16)
Total$3,024 $3,253 ($229)(7)
Billed Electric Energy Sales (GWh):
Residential10,771 10,815 (44)— 
Commercial7,947 8,564 (617)(7)
Industrial22,006 22,577 (571)(3)
Governmental590 623 (33)(5)
Total retail41,314 42,579 (1,265)(3)
Sales for resale:
Associated companies4,225 3,428 797 23 
Non-associated companies1,631 1,433 198 14 
Total47,170 47,440 (270)(1)
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ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of the COVID-19 pandemic.

Hurricane Delta

In October 2020, Hurricane Delta caused significant damage to Entergy Mississippi’s service area. The storm resulted in widespread power outages, significant damage primarily to distribution infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy Mississippi’s electric facilities in areas with damage from Hurricane Delta are currently estimated to be in the range of $30 million to $35 million. Entergy Mississippi expects to include Hurricane Delta costs in its formula rate plan 2020 look-back filing to be submitted to the MPSC in March 2021. Storm cost recovery will be subject to review by the MPSC.

Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income increased $2.4 million primarily due to higher retail electric price, partially offset by lower volume/weather, higher depreciation and amortization expenses, and higher other operation and maintenance expenses.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income increased $21.7 million primarily due to higher retail electric price, partially offset by higher depreciation and amortization expenses, lower volume/weather, and higher other operation and maintenance expenses.

Operating Revenues

Third Quarter 2020 Compared to Third Quarter 2019

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$398.7 
Fuel, rider, and other revenues that do not significantly affect net income(65.0)
Volume/weather(11.9)
Retail electric price34.7 
2020 operating revenues$356.5 

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Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to decreased usage in the unbilled sales period and decreased commercial usage as a result of the COVID-19 pandemic. Entergy Mississippi continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

The retail electric price variance is primarily due to:

•increases in formula rate plan rates effective with the first billing cycle of April 2020 and an interim capacity rate adjustment to the formula rate plan to recover non-fuel related costs of acquiring and operating the Choctaw Generating Station; and
•the implementation of a vegetation management rider effective with the April 2020 billing cycle.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the vegetation management rider.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$983.7 
Fuel, rider, and other revenues that do not significantly affect net income(100.9)
Volume/weather(14.1)
Retail electric price79.7 
2020 operating revenues$948.4 

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to the effect of less favorable weather on residential sales and decreased commercial usage as a result of the COVID-19 pandemic. The decrease was partially offset by an increase in residential usage as a result of the COVID-19 pandemic. Entergy Mississippi continues to expect declines in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.


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The retail electric price variance is primarily due to:

•increases in formula rate plan rates effective with the first billing cycles of July 2019 and April 2020 and an interim capacity rate adjustment to the formula rate plan to recover non-fuel related costs of acquiring and operating the Choctaw Generating Station; and
•the implementation of a vegetation management rider effective with the April 2020 billing cycle.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the vegetation management rider.

Other Income Statement Variances

Third Quarter 2020 Compared to Third Quarter 2019

Other operation and maintenance expenses increased primarily due to an increase of $2 million in distribution operations costs due to a higher scope of work, including contract costs, in 2020 as compared to the same period in 2019 and several individually insignificant items.

Depreciation and amortization expenses increased primarily as a result of additions to plant in service, including the Choctaw Generating Station, which was purchased in October 2019.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Other operation and maintenance expenses increased primarily due to:

•an increase of $8.7 million in storm damage provisions. See Note 2 to the financial statements in the Form 10-K for a discussion of storm cost recovery;
•an increase of $1.7 million in compensation and benefits costs primarily due to an increase in net periodic pension and other post retirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and
•several individually insignificant items.

The increase was partially offset by:

•a decrease of $6.9 million in non-nuclear generation expenses primarily due to a lower scope of work done during plant outages in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic; and
•a decrease of $3.3 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services.

Depreciation and amortization expenses increased primarily as a result of higher depreciation rates effective July 2019, as approved by the MPSC, and additions to plant in service, including the Choctaw Generating Station, which was purchased in October 2019.


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Income Taxes

The effective income tax rate was 23.2% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 20.5% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.

The effective income tax rates were 22.8% for the third quarter 2019 and 21.6% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Cash and cash equivalents at beginning of period$51,601 $36,954 
Cash flow provided by (used in):
Operating activities200,273 203,439 
Investing activities(374,978)(276,307)
Financing activities166,142 134,850 
Net increase (decrease) in cash and cash equivalents(8,563)61,982 
Cash and cash equivalents at end of period$43,038 $98,936 

Operating Activities

Net cash flow provided by operating activities decreased $3.2 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to the timing of recovery of fuel and purchased power costs and the timing of collections of receivables from customers, in part due to the COVID-19 pandemic. The decrease was partially offset by the timing of payments to vendors.
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Investing Activities

Net cash flow used in investing activities increased $98.7 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•$40.9 million in storm spending in 2020;
•$24.6 million in plant upgrades for Choctaw Generating Station in March 2020;
•an increase of $20.3 million in transmission construction expenditures primarily due to a higher scope of work performed in 2020 as compared to 2019; and
•an increase of $19.7 million in distribution construction expenditures, including increased spending on advanced metering infrastructure.

Financing Activities

Net cash flow provided by financing activities increased $31.3 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to the issuance of $170 million of 3.5% Series mortgage bonds in May 2020 and the repayment, at maturity, of $150 million of 6.64% Series mortgage bonds in July 2019, partially offset by the issuance of $300 million of 3.85% Series mortgage bonds in June 2019. 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 Mississippi’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Mississippi is primarily due to the issuance of $170 million of mortgage bonds in May 2020.
September 30,
2020		December 31,
2019
Debt to capital51.9 %51.2 %
Effect of subtracting cash(0.6 %)(0.8 %)
Net debt to net capital51.3 %50.4 %

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, finance lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and 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.

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.

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Entergy Mississippi has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. Despite the effects of the pandemic on financial markets Entergy Mississippi renewed its short-term credit facilities in April 2020 and issued $170 million of long-term mortgage bonds in May 2020. Additional discussion of Entergy Mississippi’s liquidity and capital resources follows.

Entergy Mississippi is developing its capital investment plan for 2021 through 2023 and currently anticipates making $1.5 billion in capital investments during that period. The preliminary estimate includes specific investments such as the Sunflower Solar Facility; 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.

Entergy Mississippi’s receivables from the money pool were as follows:
September 30,
2020		December 31,
2019		September 30,
2019		December 31, 2018
(In Thousands)
$3,721$44,693$8,899$41,380

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Mississippi has three separate credit facilities in the aggregate amount of $82.5 million scheduled to expire in April 2021. No borrowings were outstanding under the credit facilities as of September 30, 2020.  In addition, Entergy Mississippi is a party to an uncommitted letter of credit facility primarily as a means to post collateral to support its obligations to MISO. As of September 30, 2020, $1 million of MISO letters of credit and $1 million of non-MISO letters of credit were outstanding under this facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Entergy Mississippi has $33 million in its storm reserve escrow account at September 30, 2020.

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Sunflower Solar Facility

In November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi.  The estimated base purchase price is approximately $138.4 million.  The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 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.  The project will be built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met.  In December 2018, Entergy Mississippi filed a joint petition with Sunflower Solar Project at the MPSC for Sunflower Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility.  Entergy Mississippi has 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 annual ownership costs of the Sunflower Solar Facility. In December 2019 the MPSC approved Entergy Mississippi’s proposed revisions to its formula rate plan to provide for an interim capacity rate adjustment mechanism. Recovery through the interim capacity rate adjustment requires MPSC approval for each new resource. In August 2019 consultants retained by the Mississippi Public Utilities Staff filed a report expressing concerns regarding the project economics. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised by the consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. A hearing before the MPSC was held in March 2020. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar Facility and its recovery through the interim capacity rate adjustment mechanism, subject to certain conditions including: (i) that Entergy Mississippi pursue a partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. Closing is targeted to occur by the end of 2021.

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.

Formula Rate Plan Filings

See the Form 10-K for revisions to Entergy Mississippi’s formula rate plan approved by the MPSC in December 2019. In January 2020 Entergy Mississippi began billing an interim capacity rate adjustment rider to recover the $59 million first-year annual revenue requirement associated with the non-fuel ownership costs of the Choctaw Generating Station. Also, effective with the April 2020 billing cycle, Entergy Mississippi implemented a rider to recover $22 million in vegetation management costs. Vegetation management costs were previously recovered through the formula rate plan.

In March 2020, Entergy Mississippi submitted its formula rate plan 2020 test year filing and 2019 look-back filing showing Entergy Mississippi’s earned return for the historical 2019 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2020 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $24.6 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. The 2019 look-back filing compares actual 2019 results to the approved benchmark return on rate base and reflects the need for a $7.3 million interim increase in formula rate plan revenues. In accordance with the MPSC-approved revisions to the formula rate plan, Entergy Mississippi
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implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2019 retail revenues, effective with the April 2020 billing cycle, subject to refund. In June 2020, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2020 test year filing that showed a $23.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. Pursuant to the joint stipulation, Entergy Mississippi’s 2019 look-back filing reflected an earned return on rate base of 6.75% in calendar year 2019, which is within the look-back bandwidth. As a result, there is no change in formula rate plan revenues in the 2019 look-back filing. In June 2020 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2020.

Fuel and purchased power recovery

In November 2019, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation included $39.6 million of prior over-recovery flowing back to customers beginning February 2020. Entergy Mississippi’s balance in its deferred fuel account did not decrease as expected after implementation of the new factor. In an effort to assist customers during the COVID-19 pandemic, in May 2020, Entergy Mississippi requested an interim adjustment to the energy cost recovery rider to credit approximately $50 million from the over-recovered balance in the deferred fuel account to customers over four consecutive billing months. The MPSC approved this interim adjustment in May 2020 effective for June through September 2020 bills.

COVID-19 Orders

In March 2020 the MPSC issued an order suspending disconnections for a period of sixty days. The MPSC extended the order on disconnections through May 26, 2020. In April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. While the MPSC order on suspension of disconnections has expired, Entergy Mississippi has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy Mississippi recorded a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

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.

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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, 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.

Other Postretirement Benefits
As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, Entergy Mississippi now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $3.6 million.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.
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ENTERGY MISSISSIPPI, LLC
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$356,496 $398,732 $948,372 $983,713 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale41,771 87,386 143,798 188,006 
Purchased power68,296 78,286 177,618 223,461 
Other operation and maintenance74,891 69,253 203,571 195,357 
Taxes other than income taxes24,638 26,673 74,525 78,613 
Depreciation and amortization52,486 44,339 155,937 123,145 
Other regulatory charges (credits) - net571 5,771 (9,806)11,708 
TOTAL262,653 311,708 745,643 820,290 
OPERATING INCOME93,843 87,024 202,729 163,423 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction1,793 2,079 4,820 6,341 
Interest and investment income13 462 268 1,011 
Miscellaneous - net(2,497)(1,648)(7,382)(2,238)
TOTAL(691)893 (2,294)5,114 
INTEREST EXPENSE
Interest expense17,650 15,922 51,425 45,804 
Allowance for borrowed funds used during construction(773)(892)(1,958)(2,683)
TOTAL16,877 15,030 49,467 43,121 
INCOME BEFORE INCOME TAXES76,275 72,887 150,968 125,416 
Income taxes17,686 16,650 30,960 27,114 
NET INCOME $58,589 $56,237 $120,008 $98,302 
See Notes to Financial Statements.

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STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$120,008 $98,302 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization155,937 123,145 
Deferred income taxes, investment tax credits, and non-current taxes accrued34,848 32,596 
Changes in assets and liabilities:
Receivables(21,376)(37,843)
Fuel inventory(359)(3,872)
Accounts payable5,863 (574)
Taxes accrued(10,366)(26,556)
Interest accrued9,075 2,093 
Deferred fuel costs(45,998)47,569 
Other working capital accounts(7,372)533 
Provisions for estimated losses(28)(3,099)
Other regulatory assets(31,987)(923)
Other regulatory liabilities(10,592)(16,615)
Pension and other postretirement liabilities(11,451)(6,930)
Other assets and liabilities14,071 (4,387)
Net cash flow provided by operating activities200,273 203,439 
INVESTING ACTIVITIES
Construction expenditures(393,887)(314,622)
Allowance for equity funds used during construction4,820 6,341 
Changes in money pool receivable - net40,972 32,481 
Payment for the purchase of assets(28,612)— 
Other1,729 (507)
Net cash flow used in investing activities(374,978)(276,307)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt165,399 292,763 
Retirement of long-term debt— (150,000)
Common equity distributions paid(7,500)— 
Other8,243 (7,913)
Net cash flow provided by financing activities166,142 134,850 
Net increase (decrease) in cash and cash equivalents(8,563)61,982 
Cash and cash equivalents at beginning of period51,601 36,954 
Cash and cash equivalents at end of period$43,038 $98,936 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$40,551 $41,753 
See Notes to Financial Statements.
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BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
 20202019
 (In Thousands)
CURRENT ASSETS  
Cash and cash equivalents:  
Cash$16 $11 
Temporary cash investments43,022 51,590 
Total cash and cash equivalents43,038 51,601 
Accounts receivable:  
Customer108,365 92,050 
Allowance for doubtful accounts(11,385)(636)
Associated companies10,436 49,257 
Other16,181 14,986 
Accrued unbilled revenues59,890 47,426 
Total accounts receivable183,487 203,083 
Fuel inventory - at average cost15,498 15,139 
Materials and supplies - at average cost60,882 57,972 
Prepayments and other7,768 7,149 
TOTAL310,673 334,944 
OTHER PROPERTY AND INVESTMENTS  
Non-utility property - at cost (less accumulated depreciation)4,547 4,560 
Escrow accounts80,326 80,201 
TOTAL84,873 84,761 
UTILITY PLANT  
Electric5,917,691 5,672,589 
Construction work in progress169,686 88,373 
TOTAL UTILITY PLANT6,087,377 5,760,962 
Less - accumulated depreciation and amortization1,979,372 1,894,000 
UTILITY PLANT - NET4,108,005 3,866,962 
DEFERRED DEBITS AND OTHER ASSETS  
Regulatory assets:  
Other regulatory assets409,959 377,972 
Other15,840 10,105 
TOTAL425,799 388,077 
TOTAL ASSETS$4,929,350 $4,674,744 
See Notes to Financial Statements.  
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BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
 20202019
 (In Thousands)
CURRENT LIABILITIES  
Accounts payable:  
Associated companies$42,287 $48,090 
Other95,917 94,729 
Customer deposits86,417 85,938 
Taxes accrued80,295 90,661 
Interest accrued27,975 18,900 
Deferred fuel costs24,404 70,402 
Other45,910 32,667 
TOTAL403,205 441,387 
NON-CURRENT LIABILITIES  
Accumulated deferred income taxes and taxes accrued639,865 594,832 
Accumulated deferred investment tax credits9,482 9,602 
Regulatory liability for income taxes - net228,993 236,988 
Other regulatory liabilities18,915 21,512 
Asset retirement cost liabilities9,629 9,727 
Accumulated provisions49,993 50,021 
Pension and other postretirement liabilities87,971 99,406 
Long-term debt1,780,310 1,614,129 
Other46,328 54,989 
TOTAL2,871,486 2,691,206 
Commitments and Contingencies  
EQUITY  
Member's equity1,654,659 1,542,151 
TOTAL1,654,659 1,542,151 
TOTAL LIABILITIES AND EQUITY$4,929,350 $4,674,744 
See Notes to Financial Statements.  
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STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
  
 Member's Equity
 (In Thousands)
Balance at December 31, 2018$1,292,226 
Net income15,398 
Balance at March 31, 20191,307,624 
Net income26,667 
Balance at June 30, 20191,334,291 
Net income56,237 
Balance at September 30, 2019$1,390,528 
Balance at December 31, 2019$1,542,151 
Net income22,526 
Common equity distributions(2,500)
Balance at March 31, 20201,562,177 
Net income38,893 
Balance at June 30, 20201,601,070 
Net income58,589 
Common equity distributions(5,000)
Balance at September 30, 2020$1,654,659 
See Notes to Financial Statements.
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ENTERGY MISSISSIPPI, LLC
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
 Three Months EndedIncrease/ 
20202019(Decrease)%
 (Dollars In Millions) 
Electric Operating Revenues:    
Residential$161 $178 ($17)(10)
Commercial109 132 (23)(17)
Industrial34 44 (10)(23)
Governmental11 12 (1)(8)
Total billed retail315 366 (51)(14)
Sales for resale:    
Non-associated companies30 10 20 200 
Other11 23 (12)(52)
Total$356 $399 ($43)(11)
    
Billed Electric Energy Sales (GWh):    
Residential1,855 1,832 23 1 
Commercial1,298 1,403 (105)(7)
Industrial629 654 (25)(4)
Governmental115 126 (11)(9)
Total retail3,897 4,015 (118)(3)
Sales for resale:    
Non-associated companies1,762 472 1,290 273 
Total5,659 4,487 1,172 26 
 Nine Months EndedIncrease/ 
20202019(Decrease)%
 (Dollars In Millions) 
Electric Operating Revenues:    
Residential$400 $423 ($23)(5)
Commercial296 332 (36)(11)
Industrial106 121 (15)(12)
Governmental31 33 (2)(6)
Total billed retail833 909 (76)(8)
Sales for resale:    
Non-associated companies62 19 43 226 
Other53 56 (3)(5)
Total$948 $984 ($36)(4)
    
Billed Electric Energy Sales (GWh):
Residential4,222 4,307 (85)(2)
Commercial3,270 3,548 (278)(8)
Industrial1,747 1,808 (61)(3)
Governmental299 327 (28)(9)
Total retail9,538 9,990 (452)(5)
Sales for resale:    
Non-associated companies3,628 852 2,776 326 
Total13,166 10,842 2,324 21 
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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of the COVID-19 pandemic.

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to portions of Entergy's service area in Louisiana, including New Orleans. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Entergy is still assessing and developing an estimate of the total restoration costs for the repair and/or replacement of the infrastructure damaged by Hurricane Zeta. Entergy is considering all available avenues to recover storm-related costs from Hurricane Zeta, including accessing funded storm reserve escrows and securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income decreased $5.5 million primarily due to lower volume/weather.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income decreased $11.4 million primarily due to lower retail electric price and lower volume/weather.

Operating Revenues

Third Quarter 2020 Compared to Third Quarter 2019

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$194.2 
Fuel, rider, and other revenues that do not significantly affect net income(6.5)
Volume/weather(5.6)
2020 operating revenues$182.1 

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

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The volume/weather variance is primarily due to a decrease of 122 GWh, or 7%, in billed electricity usage, including the effect of decreased commercial usage as a result of the COVID-19 pandemic, and the effect of unfavorable weather on commercial and residential sales. Entergy New Orleans continues to expect a decline in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial customer class. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$533.2 
Fuel, rider, and other revenues that do not significantly affect net income(28.8)
Retail electric price(14.9)
Volume/weather(10.8)
2020 operating revenues$478.7 

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to the effects of a rate reduction implemented with April 2020 bills that was effective August 2019 in accordance with the City Council resolution and related agreement in principle reached in the 2018 base rate case. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the rate case.

The volume/weather variance is primarily due to a decrease of 246 GWh, or 6%, in billed electricity usage, including the effect of decreased commercial and governmental usage as a result of the COVID-19 pandemic and the effect of less favorable weather on residential sales, partially offset by an increase in residential usage as a result of the COVID-19 pandemic. Entergy New Orleans continues to expect a decline in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial customer class. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

Other Income Statement Variances

Third Quarter 2020 Compared to Third Quarter 2019

Other operation and maintenance expenses increased primarily due to an increase of $2.7 million in energy efficiency costs, partially offset by a decrease of $1 million in loss provisions.

Other income decreased primarily due to a decrease in allowance for equity funds used during construction resulting from higher construction work in progress in 2019, including the New Orleans Power Station project.

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Interest expense increased primarily due to the issuance of:

•$78 million of 3.00% Series mortgage bonds in March 2020;
•$62 million of 3.75% Series mortgage bonds in March 2020; and
•a $70 million term loan at 3.0% in December 2019.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Other operation and maintenance expenses decreased primarily due to a decrease of $2.3 million in information technology costs primarily due to lower costs related to system conversion for Algiers customers and a decrease of $2 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services. The decrease was partially offset by an increase of $2.6 million in energy efficiency costs and an increase of $1.2 million in compensation and benefits costs.

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

Other regulatory charges include regulatory credits recorded in the first quarter 2020 to reflect compliance with terms of the 2018 combined rate case resolution approved by the City Council in February 2020. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the rate case resolution.

Interest expense increased primarily due to the issuance of:

•a $70 million term loan at 3.0% in December 2019;
•$78 million of 3.00% Series mortgage bonds in March 2020; and
•$62 million of 3.75% Series mortgage bonds in March 2020.

Income Taxes

The effective income tax rate was 23.9% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes and the provision for uncertain tax positions, partially offset by certain book and tax differences related to utility plant items and the amortization of excess accumulated deferred income taxes. See Note 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 4.4% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 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, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes and the provision for uncertain tax positions. See Note 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 discussion of the income tax deductions for stock-based compensation.

The effective income tax rates were 3.6% for the third quarter 2019 and 10.2% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were 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 state income taxes and the provision for uncertain tax positions. See Note 10 to the financial statements herein and Notes
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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.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion.  Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Cash and cash equivalents at beginning of period$6,017 $19,677 
Cash flow provided by (used in):
Operating activities46,097 77,433 
Investing activities(169,565)(136,817)
Financing activities117,483 39,733 
Net decrease in cash and cash equivalents(5,985)(19,651)
Cash and cash equivalents at end of period$32 $26 

Operating Activities

Net cash flow provided by operating activities decreased $31.3 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the timing of recovery of fuel and purchased power costs;
•income tax payments of $3.3 million made in 2020 compared to income tax refunds of $4.9 million received in 2019, each in accordance with an intercompany income tax allocation agreement. The income tax refunds resulted from the utilization of Entergy New Orleans’s net operating loss;
•an increase of $4 million in interest paid in 2020; and
•the timing of collection of receivables from customers, in part due to the COVID-19 pandemic.

The decrease was partially offset by the timing of payments to vendors.

Investing Activities

Net cash flow used in investing activities increased $32.7 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•money pool activity;
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•an increase of $12 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy New Orleans’s distribution system, including increased spending on advanced metering infrastructure; and
•an increase of $2.9 million in facilities construction expenditures primarily due to a higher scope of work performed in 2020.

The increase was partially offset by:

•a decrease of $5.5 million in transmission construction expenditures primarily due to the timing of work performed in 2020 as compared to the same period in 2019; and
•a decrease of $0.7 million in non-nuclear generation construction expenditures primarily due to lower spending in 2020 on the New Orleans Power Station project, partially offset by higher spending in 2020 on the New Orleans Solar Station project.

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 $5.2 million for the nine months ended September 30, 2020 compared to decreasing $22 million for the nine months ended September 30, 2019. 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 $77.8 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to the issuance of $78 million of 3.00% Series mortgage bonds and the issuance of $62 million of 3.75% Series mortgage bonds, each in March 2020. The increase was partially offset by money pool activity and an increase of repayments of $20 million on long-term credit borrowings in 2020.

Increases in Entergy New Orleans’s payable to the money pool are a source of cash flow, and Entergy New Orleans’s payable to the money pool increased $5.1 million for the nine months ended September 30, 2020 compared to increasing by $46.3 million for the nine months ended September 30, 2019.

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 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 $140 million of mortgage bonds in March 2020.
September 30,
2020		December 31,
2019
Debt to capital56.0 %53.1 %
Effect of excluding securitization bonds (1.8 %)(2.4 %)
Debt to capital, excluding securitization bonds (a)54.2 %50.7 %
Effect of subtracting cash— %(0.3 %)
Net debt to net capital, excluding securitization bonds (a)54.2 %50.4 %

(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, finance lease obligations, long-term debt, including the currently maturing portion, and the long-term payable due to an
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associated company.  Capital consists of debt and 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 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 has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. Despite the effects of the pandemic on financial markets Entergy New Orleans issued $140 million of long-term mortgage bonds in March 2020. Additional discussion of Entergy New Orleans’s liquidity and capital resources follows.

Entergy New Orleans is developing its capital investment plan for 2021 through 2023 and currently anticipates making $480 million in capital investments during that period. The preliminary estimate includes 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; 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:
September 30,
2020		December 31,
2019		September 30,
2019		December 31,
2018
(In Thousands)
($5,089)$5,191($46,318)$22,016

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in November 2021. 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 September 30, 2020, there were no cash borrowings and an $0.8 million letter of credit 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 September 30, 2020, a $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.

Entergy New Orleans has $83 million in its storm reserve escrow account at September 30, 2020. As discussed in “COVID-19 Orders” below, the City Council has directed Entergy New Orleans to use approximately $15 million of its storm reserve escrow to fund the City Council Cares Program.
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New Orleans Power Station

As discussed in the Form 10-K, in June 2019, a state court judge in New Orleans affirmed the City Council’s approval of the New Orleans Power Station and dismissed the petition for judicial review of that decision that had been filed in April 2018. The petitioners have filed an appeal of that ruling. Also in June 2019, with regard to the lawsuit challenging the City Council’s decision on the basis of a violation of the open meetings law, the same state court judge in New Orleans ruled that there was a violation of the open meetings law at the February 2018 meeting of the City Council’s Utility Committee at which that Committee considered the New Orleans Power Station approval, and further ruled that, although there was no violation of the open meetings law at the March 2018 City Council meeting at which the New Orleans Power Station was approved, both the approval of the Utility Committee and the approval of the City Council were void. The City Council and Entergy New Orleans each filed a suspensive appeal of the open meetings law ruling. A suspensive appeal suspends the effect of the judgment in the open meetings law proceeding while the appeal is being taken. The petitioners sought in the state appellate court, and then at the Louisiana Supreme Court, to terminate the suspension of the effect of the judgment, but both courts declined to do so. Oral argument in both cases was heard in January 2020. In February 2020 the state appellate court reversed the lower court’s ruling that the City Council’s approval of the New Orleans Power Station was void due to a violation of the open meetings law at the City Council’s Utility Committee meeting in February 2018.  The state appellate court ruled that there was no violation of the open meetings law at the City Council meeting in March 2018 and that the lower court erred in voiding the City Council resolution approving the New Orleans Power Station.  In March 2020 the appellees in that proceeding filed a writ application with the Louisiana Supreme Court seeking review of the appellate court’s decision and several New Orleans-based organizations filed an amicus brief in support of the appellees’ writ application. Entergy New Orleans and the City Council each filed an opposition to the writ application in June 2020, and the City Council also filed its own writ application seeking reversal of the appellate court’s holding that there was a violation of the open meetings law at the February 2018 City Council’s Utility Committee meeting. In its writ application the City Council requested that the Louisiana Supreme Court deny the appellees’ writ application, and grant the City Council’s writ application only if the Supreme Court grants the appellees’ writ application. In April 2020 the state appellate court affirmed the district court’s judicial review decision that affirmed the City Council’s approval of the New Orleans Power Station as in the public interest. In June 2020 appellants in that case filed a writ application with the Louisiana Supreme Court seeking review and reversal of that appellate court ruling. In July 2020 the City Council and Entergy New Orleans each filed an opposition to appellants’ writ application in the judicial review case. Commercial operation of the plant commenced in May 2020. In accordance with the City Council resolution issued in the 2018 base rate case proceeding, Entergy New Orleans has been deferring the New Orleans Power Station non-fuel costs pending the conclusion of the appellate proceedings. In October 2020 the Louisiana Supreme Court denied all writ applications relating to the New Orleans Power Station. With those denials, Entergy New Orleans expects to begin recovering New Orleans Power Station costs in rates as early as November 2020.

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, which would replace all of Entergy New Orleans’s low pressure cast iron, steel, and vintage plastic pipe over a ten-year period commencing in 2017.  Entergy New Orleans also proposed that recovery of the investment to fund its gas infrastructure replacement plan be determined in connection with its next base rate case.  As a result of the rate case, the City Council approved the planned gas rebuild expenditures through 2019, but rejected Entergy New Orleans’s proposed gas infrastructure rider. In April 2020, Entergy New Orleans submitted its gas infrastructure rebuild plan to the City Council, which maintained the previously proposed timeline and cost estimates, but included measures to spread out the cost impact to customers of the program.

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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 Efficiency

As discussed in the Form 10-K, in December 2019, Entergy New Orleans filed an application with the City Council seeking approval of an implementation plan for the Energy Smart energy efficiency program from April 2020 through December 2022. Entergy New Orleans proposed to recover the costs of the program through mechanisms previously approved by the City Council or through the energy efficiency cost recovery rider, which was approved in the 2018 combined rate case resolution. In February 2020 the City Council approved Entergy New Orleans’s application.

2018 Base Rate Case Filing

See the Form 10-K for discussion of the electric and gas base rate case filed in September 2018. In response to the City Council’s November 2019 resolution in the rate case, Entergy New Orleans made a compliance filing in December 2019 and also filed timely a petition for appeal and judicial review and for stay of or injunctive relief alleging that the resolution is unlawful in failing to produce just and reasonable rates. A hearing on the requested injunction was scheduled in Civil District Court for February 2020, but by joint motion of the City Council and Entergy New Orleans, the Civil District Court issued an order for a limited remand to the City Council to consider a potential agreement in principle/stipulation at its February 20, 2020 meeting. On February 17, 2020, Entergy New Orleans filed with the City Council an agreement in principle between Entergy New Orleans and the City Council’s advisors. On February 20, 2020, the City Council voted to approve the proposed agreement in principle and issued a resolution modifying the required treatment of certain accumulated deferred income taxes. As a result of the agreement in principle, the total annual revenue requirement reduction will be approximately $45 million ($42 million electric, including $29 million in rider reductions; and $3 million gas). Entergy New Orleans fully implemented the new rates in April 2020. In accordance with the provisions of the agreement in principle approved by the City Council related to the 2020 formula rate plan filing, Entergy New Orleans anticipates moving forward with dismissal of its judicial review petition in the Civil District Court.

2020 Formula Rate Plan Filing

Entergy New Orleans’s first annual filing under the three-year formula rate plan approved by the City Council in November 2019 was originally due to be filed in April 2020. The authorized return on equity under the approved three-year formula rate plan is 9.35% for both electric and gas operations. The City Council approved several extensions of the deadline to allow additional time to assess the effects of the COVID-19 pandemic on the New Orleans community, Entergy New Orleans customers, and Entergy New Orleans itself. In October 2020 the City Council approved an agreement in principle filed by Entergy New Orleans that results in Entergy New Orleans foregoing its 2020 formula rate plan filing and shifting the three-year formula rate plan to filings in 2021, 2022, and 2023. Key provisions of the agreement in principle include: changing the lower of actual equity ratio or 50% equity ratio approved in the rate case to a hypothetical capital structure of 51% equity and 49% debt for the duration of the three-year formula rate plan; changing the 2% depreciation rate for the New Orleans Power Station approved in the rate case to 3%; retention of over-recovery of $2.2 million in rider revenues; recovery of $1.4 million of certain rate case expenses outside of the earnings band; recovery of the New Orleans Solar Station costs upon commercial operation; and Entergy New Orleans’s dismissal of its 2018 rate case appeal.

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COVID-19 Orders

In March 2020, Entergy New Orleans voluntarily suspended customer disconnections for non-payment of utility bills through May 2020. Subsequently, the City Council ordered that the moratorium be extended to August 1, 2020. In May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. While the City Council moratorium on customer disconnections has expired, Entergy New Orleans has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy New Orleans recorded a regulatory asset of $8.4 million for costs associated with the COVID-19 pandemic.

In June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which is intended to provide temporary bill relief to customers who become unemployed during the COVID-19 pandemic. The program became effective July 1, 2020, and offers qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of September 30, 2020, credits of $1.9 million have been applied to customer bills under the City Council Cares Program.

Renewable Portfolio Standard Rulemaking    

As discussed in the Form 10-K, in March 2019 the City Council initiated a rulemaking proceeding to consider whether to establish a renewable portfolio standard. In March 2020 the City Council’s Utility Committee recommended a resolution for approval by the City Council that directed the City Council advisors to work toward development of a rule for enacting a Renewable and Clean Portfolio Standard. The four components of the Renewable and Clean Portfolio Standard that the City Council expressed a desire to implement are: (1) a mandatory requirement that Entergy New Orleans achieve 100% net zero carbon emissions by 2040; (2) reliance on renewable energy credits purchased without the associated energy for compliance with the standard being phased out over the ten-year period from 2040 to 2050; (3) no carbon-emitting resources in the portfolio of resources Entergy New Orleans uses to serve New Orleans by 2050; and (4) a mechanism to limit costs in any one plan year to no more than one percent of plan year total utility retail sales revenues. The City Council adopted the Utility Committee resolution in April 2020. The first technical meeting of the parties occurred in June 2020; a second technical meeting occurred in July 2020. In August 2020 the City Council advisors issued a final draft of the rules for review and comment from the parties before final rules are proposed for consideration by the City Council. Entergy New Orleans filed comments in September and October 2020. A City Council decision is expected in December 2020.

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 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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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, 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.

Other Postretirement Benefits

As described in Note 6 to the financial statements herein, Entergy announced changes to its other postretirement benefits. As a result, Entergy New Orleans now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $4.9 million.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$169,512 $176,738 $427,842 $464,773 
Natural gas12,552 17,466 50,867 68,418 
TOTAL182,064 194,204 478,709 533,191 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale15,051 27,013 59,382 84,963 
Purchased power66,868 68,091 181,320 195,721 
Other operation and maintenance34,872 32,755 94,702 95,305 
Taxes other than income taxes15,455 15,142 44,303 41,819 
Depreciation and amortization16,134 14,756 46,835 43,146 
Other regulatory charges - net1,362 7,571 152 9,716 
TOTAL149,742 165,328 426,694 470,670 
OPERATING INCOME32,322 28,876 52,015 62,521 
OTHER INCOME
Allowance for equity funds used during construction910 2,793 5,443 7,769 
Interest and investment income13 109 109 352 
Miscellaneous - net(600)(1,019)(1,170)(3,467)
TOTAL323 1,883 4,382 4,654 
INTEREST EXPENSE
Interest expense7,529 6,046 21,804 18,001 
Allowance for borrowed funds used during construction(438)(1,115)(2,618)(3,102)
TOTAL7,091 4,931 19,186 14,899 
INCOME BEFORE INCOME TAXES25,554 25,828 37,211 52,276 
Income taxes6,104 920 1,646 5,342 
NET INCOME$19,450 $24,908 $35,565 $46,934 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$35,565 $46,934 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization46,835 43,146 
Deferred income taxes, investment tax credits, and non-current taxes accrued10,382 20,427 
Changes in assets and liabilities:
Receivables(10,892)(14,741)
Fuel inventory190 (374)
Accounts payable1,841 (11,654)
Taxes accrued(2,283)242 
Interest accrued(335)14 
Deferred fuel costs(5,629)8,328 
Other working capital accounts(14,122)(8,737)
Provisions for estimated losses1,356 1,423 
Other regulatory assets2,196 (14,435)
Other regulatory liabilities(13,389)(15,371)
Pension and other postretirement liabilities(10,373)(5,784)
Other assets and liabilities4,755 28,015 
Net cash flow provided by operating activities46,097 77,433 
INVESTING ACTIVITIES
Construction expenditures(174,011)(162,177)
Allowance for equity funds used during construction5,443 7,769 
Payment for purchase of assets(1,584)— 
Changes in money pool receivable - net5,191 22,016 
Payments to storm reserve escrow account(428)(1,382)
Changes in securitization account(4,176)(3,043)
Net cash flow used in investing activities(169,565)(136,817)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt138,930 — 
Retirement of long-term debt(25,616)(5,420)
Change in money pool payable - net5,089 46,318 
Other(920)(1,165)
Net cash flow provided by financing activities117,483 39,733 
Net decrease in cash and cash equivalents(5,985)(19,651)
Cash and cash equivalents at beginning of period6,017 19,677 
Cash and cash equivalents at end of period$32 $26 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$21,203 $17,211 
Income taxes$3,332 ($4,899)
See Notes to Financial Statements.
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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents
Cash$32 $26 
Temporary cash investments— 5,991 
Total cash and cash equivalents32 6,017 
Securitization recovery trust account6,165 1,989 
Accounts receivable: 
Customer67,572 48,265 
Allowance for doubtful accounts(12,025)(3,226)
Associated companies2,448 6,280 
Other5,630 7,378 
Accrued unbilled revenues26,226 25,453 
Total accounts receivable89,851 84,150 
Deferred fuel costs711 — 
Fuel inventory - at average cost1,730 1,920 
Materials and supplies - at average cost15,609 13,522 
Prepayments and other5,806 4,846 
TOTAL119,904 112,444 
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)1,016 1,016 
Storm reserve escrow account83,033 82,605 
TOTAL84,049 83,621 
UTILITY PLANT
Electric1,712,743 1,467,215 
Natural gas330,021 311,432 
Construction work in progress74,915 201,829 
TOTAL UTILITY PLANT2,117,679 1,980,476 
Less - accumulated depreciation and amortization740,115 715,406 
UTILITY PLANT - NET1,377,564 1,265,070 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs4,080 4,080 
Other regulatory assets (includes securitization property of $38,969 as of September 30, 2020 and $49,542 as of December 31, 2019)
257,167 259,363 
Other20,975 10,720 
TOTAL282,222 274,163 
TOTAL ASSETS$1,863,739 $1,735,298 
See Notes to Financial Statements.
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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$25,000 $25,000 
Payable due to associated company1,838 1,838 
Accounts payable:
Associated companies46,266 43,222 
Other35,789 43,963 
Customer deposits28,092 28,493 
Taxes accrued2,019 4,302 
Interest accrued6,581 6,916 
Deferred fuel costs— 4,918 
Current portion of unprotected excess accumulated deferred income taxes3,296 9,470 
Other5,301 15,827 
TOTAL154,182 183,949 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued368,411 354,536 
Accumulated deferred investment tax credits2,085 2,131 
Regulatory liability for income taxes - net46,771 49,090 
Asset retirement cost liabilities3,705 3,522 
Accumulated provisions89,898 88,542 
Long-term debt (includes securitization bonds of $47,207 as of September 30, 2020 and
   $52,641 as of December 31, 2019)
635,465 521,539 
Long-term payable due to associated company12,529 12,529 
Other17,549 21,881 
TOTAL1,176,413 1,053,770 
Commitments and Contingencies
EQUITY
Member's equity533,144 497,579 
TOTAL533,144 497,579 
TOTAL LIABILITIES AND EQUITY$1,863,739 $1,735,298 
See Notes to Financial Statements.
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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
  
 Member's Equity
 (In Thousands)
Balance at December 31, 2018$444,950 
Net income9,023 
Balance at March 31, 2019453,973 
Net income13,003 
Balance at June 30, 2019466,976 
Net income24,908 
Balance at September 30, 2019$491,884 
Balance at December 31, 2019$497,579 
Net income11,186 
Balance at March 31, 2020508,765 
Net income4,929 
Balance at June 30, 2020513,694 
Net income19,450 
Balance at September 30, 2020$533,144 
See Notes to Financial Statements. 

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SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
 Three Months EndedIncrease/ 
20202019(Decrease)%
 (Dollars In Millions) 
Electric Operating Revenues:   
Residential$83 $82 $1 1 
Commercial51 56 (5)(9)
Industrial7 9 (2)(22)
Governmental17 19 (2)(11)
Total billed retail158 166 (8)(5)
Sales for resale:    
Non-associated companies9 7 2 29 
Other2 4 (2)(50)
Total$169 $177 ($8)(5)
Billed Electric Energy Sales (GWh):    
Residential773 793 (20)(3)
Commercial564 645 (81)(13)
Industrial120 124 (4)(3)
Governmental211 228 (17)(7)
Total retail1,668 1,790 (122)(7)
Sales for resale:    
Non-associated companies588 364 224 62 
Total2,256 2,154 102 5 
 Nine Months EndedIncrease/ 
20202019(Decrease)%
 (Dollars In Millions) 
Electric Operating Revenues:   
Residential$188 $192 ($4)(2)
Commercial132 156 (24)(15)
Industrial18 24 (6)(25)
Governmental44 54 (10)(19)
Total billed retail382 426 (44)(10)
Sales for resale:    
  Non-associated companies27 26 1 4 
Other19 13 6 46 
Total$428 $465 ($37)(8)
Billed Electric Energy Sales (GWh):    
Residential1,794 1,821 (27)(1)
Commercial1,500 1,686 (186)(11)
Industrial328 326 2 1 
Governmental572 607 (35)(6)
Total retail4,194 4,440 (246)(6)
Sales for resale:    
Non-associated companies1,662 1,353 309 23 
Total5,856 5,793 63 1 
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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of the COVID-19 pandemic.

Hurricane Laura

In August 2020, Hurricane Laura caused extensive damage to Entergy Texas’s service area. The storm resulted in power outages and significant damage primarily to distribution and transmission infrastructure. Total restoration costs for the repair and/or replacement of Entergy Texas’s electric facilities damaged by Hurricane Laura are currently estimated to be in the range of $230 million to $260 million. Entergy Texas is considering all available avenues to recover storm-related costs from Hurricane Laura, including securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Entergy Texas has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy Texas recorded corresponding regulatory assets of approximately $40 million and construction work in progress of approximately $190 million. Entergy Texas recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy Texas has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy Texas is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

Hurricane Delta

In October 2020, Hurricane Delta caused significant damage to Entergy Texas’s service area. The storm resulted in widespread power outages, significant damage primarily to distribution infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy Texas’s electric facilities in areas with damage from Hurricane Delta are currently estimated to be in the range of $40 million to $50 million. Entergy Texas is considering all available avenues to recover storm-related costs from Hurricane Delta, including securitization. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income increased $18.9 million primarily due to lower other operation and maintenance expenses, higher retail electric price, lower taxes other than income taxes, and higher other income, partially offset by higher depreciation and amortization expenses.


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Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income increased $38.2 million primarily due to higher retail electric price, higher other income, lower other operation and maintenance expenses, a lower effective income tax rate, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes, and lower taxes other than income taxes, partially offset by higher depreciation and amortization expenses.

Operating Revenues

Third Quarter 2020 Compared to Third Quarter 2019

Following is an analysis of the change in operating revenues comparing the third quarter 2020 to the third quarter 2019:
Amount
(In Millions)
2019 operating revenues$442.9 
Fuel, rider, and other revenues that do not significantly affect net income27.6 
Return of unprotected excess accumulated deferred income taxes to customers20.9 
Retail electric price5.6 
Volume/weather(2.1)
2020 operating revenues$494.9 

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a rider effective October 2018. In third quarter 2020, $10 million was returned to customers as compared to $30.9 million in third quarter 2019. There is no effect on net income as the reduction in operating revenues 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 Cuts and Jobs Act.

The retail electric price variance is primarily due to an increase in the transmission cost recovery factor rider effective January 2020. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the transmission cost recovery factor rider filing.     

The volume/weather variance is primarily due to a decrease in usage during the unbilled sales period and decreased commercial and industrial usage as a result of the COVID-19 pandemic. Entergy Texas continues to expect a decline in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.


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Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2020 to the nine months ended September 30, 2019:
Amount
(In Millions)
2019 operating revenues$1,146.9 
Fuel, rider, and other revenues that do not significantly affect net income(15.1)
Return of unprotected excess accumulated deferred income taxes to customers51.2 
Retail electric price21.7 
Volume/weather1.8 
2020 operating revenues$1,206.5 

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a rider effective October 2018. In the nine months ended September 30, 2020, $22.3 million was returned to customers as compared to $73.5 million in the nine months ended September 30, 2019. There is no effect on net income as the reduction in operating revenues 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 Cuts and Jobs Act.

The retail electric price variance is primarily due to an increase in the transmission cost recovery factor rider effective January 2020. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the transmission cost recovery factor rider filing.

The volume/weather variance is primarily due to an increase in residential usage as a result of the COVID-19 pandemic, partially offset by the effect of less favorable weather on residential sales and decreased commercial usage as a result of the COVID-19 pandemic. Entergy Texas continues to expect a decline in sales volume during 2020 due to the COVID-19 pandemic, especially in the commercial and industrial customer classes. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic.

Other Income Statement Variances

Third Quarter 2020 Compared to Third Quarter 2019

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $3.2 million in non-nuclear generation expenses primarily due to a lower scope of work performed in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic;
•a decrease of $1.4 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services;
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•a decrease of $1.1 million in vegetation management costs; and
•several individually insignificant items.

Taxes other than income taxes decreased primarily due to a decrease in ad valorem taxes resulting from a millage decrease and a change in estimated property assessments.

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 2020, including the Montgomery County Power Station project.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Other operation and maintenance expenses decreased primarily due to:

•a decrease of $8.9 million in non-nuclear generation expenses primarily due to a lower scope of work done during plant outages in 2020 as compared to the same period in 2019, including a delay in plant outages as a result of the COVID-19 pandemic;
•a decrease of $3.3 million primarily due to contract costs in 2019 related to initiatives to explore new customer products and services; and
•a decrease of $1.5 million in energy efficiency costs due to the timing of recovery from customers.

The decrease was partially offset by an increase of $2.7 million in distribution operations costs primarily due to higher contract costs for meter services.

Taxes other than income taxes decreased primarily due to a decrease in ad valorem taxes resulting from a millage decrease and a change in estimated property assessments.

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 2020, including the Montgomery County Power Station project.

Income Taxes

The effective income tax rate was 10.9% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and book and tax differences related to the allowance for equity funds used during construction. See Note 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.

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The effective income tax rate was 5.3% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, book and tax differences related to the allowance for equity funds used during construction, permanent differences related to income tax deductions for stock-based compensation, and certain book and tax differences related to utility plant items. See Note 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 income tax deductions for stock-based compensation.    

The effective income tax rates were (22.6%) for the third quarter 2019 and (48.1%) for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and book and tax differences related to the allowance for equity funds used during construction. See Note 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.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Cash and cash equivalents at beginning of period$12,929 $56 
Cash flow provided by (used in):
Operating activities294,253 174,881 
Investing activities(657,427)(603,077)
Financing activities350,279 520,418 
Net increase (decrease) in cash and cash equivalents(12,895)92,222 
Cash and cash equivalents at end of period$34 $92,278 

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Operating Activities

Net cash flow provided by operating activities increased $119.4 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to the timing of recovery of fuel and purchased power costs and a decrease in the return of unprotected excess accumulated deferred income taxes to customers. The increase was partially offset by the timing of collection of receivables from customers, in part due to the COVID-19 pandemic. See Note 2 to the financial statements in the Form 10-K and Note 10 to the financial statements herein for a discussion of the effects and the regulatory activity regarding the Tax Cuts and Jobs Act.

Investing Activities

Net cash flow used in investing activities increased $54.4 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•an increase of $68.1 million in distribution construction expenditures, primarily due to investment in the reliability and infrastructure of Entergy Texas’s distribution system, including increased spending on advanced metering infrastructure;
•an increase of $62 million in transmission construction expenditures primarily due to a higher scope of work performed in 2020 as compared to 2019; and
•an increase of $17.4 million in storm spending in 2020, primarily due to Hurricane Laura restoration efforts.

The increase was partially offset by a decrease of $66.5 million in non-nuclear generation construction expenditures primarily due to the Montgomery County Power Station in 2020 as compared to 2019 and 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 $11.2 million for the nine months ended September 30, 2020 compared to increasing $8.3 million for the nine months ended September 30, 2019. 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 $170.1 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to:

•the issuances of $300 million of 4.0% Series mortgage bonds and $400 million of 4.5% Series mortgage bonds, each in January 2019;
•the issuance of $300 million of 3.55% Series mortgage bonds in September 2019; and
•the issuance of $35 million aggregate liquidation value 5.375% Series A preferred stock in September 2019.

The decrease was partially offset by:

•the repayment, at maturity, of $500 million of 7.125% Series mortgage bonds in February 2019;
•the issuance of $175 million of 3.55% Series mortgage bonds in March 2020;
•an increase of $87.5 million in capital contributions received from Entergy Corporation in anticipation of upcoming expenditures, including Montgomery County Power Station; and
•money pool activity.

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 $54.2 million for the nine months ended September 30, 2020 compared to decreasing $22.4 million for the nine months ended September 30, 2019.
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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 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 $175 million capital contribution received from Entergy Corporation in March 2020 and net income in 2020, partially offset by the issuance of $175 million of mortgage bonds in March 2020.
September 30,
2020		December 31,
2019
Debt to capital48.9 %51.7 %
Effect of excluding the securitization bonds(1.7 %)(2.8 %)
Debt to capital, excluding securitization bonds (a)47.2 %48.9 %
Effect of subtracting cash— %(0.2 %)
Net debt to net capital, excluding securitization bonds (a)47.2 %48.7 %

(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 finance lease obligations and long-term debt, including the currently maturing portion.  Capital consists of debt and 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.

Entergy Texas has experienced negative changes during 2020 to its customer payment patterns and its operating cash flow activity due to the COVID-19 pandemic, and expects them to continue throughout 2020. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the COVID-19 pandemic. Despite the effects of the pandemic on financial markets Entergy Texas issued $775 million of long-term mortgage bonds since March 2020. Additional discussion of Entergy Texas’s liquidity and capital resources follows.

Entergy Texas is developing its capital investment plan for 2021 through 2023 and currently anticipates making $2.2 billion in capital investments during that period. The preliminary estimate includes specific investments such as the Montgomery County Power Station and the Liberty County Solar Facility; 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,
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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:
September 30,
2020		December 31,
2019		September 30,
2019		December 31,
2018
(In Thousands)
($54,229)$11,181$8,299($22,389)

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 September 2024.  The credit facility includes fronting commitments for the issuance of letters of credit against $30 million of the borrowing capacity of the facility. As of September 30, 2020, there were no cash borrowings and $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 September 30, 2020, $27.2 million in letters of credit were 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.

Liberty County Solar Facility

In September 2020, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquire the 100 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisition of the facility through a tax equity partnership is in the public interest. The application is currently pending before the PUCT with a resolution anticipated by September 2021.

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.

Distribution Cost Recovery Factor (DCRF) Rider

In March 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect approximately $23.6 million annually, or $20.4 million in incremental annual DCRF revenue beyond Entergy Texas’s currently effective DCRF rider from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2019 and December 31, 2019. In May and June 2020 intervenors filed testimony recommending reductions in Entergy Texas’s annual revenue requirement of approximately $0.3 million and $4.1 million. In June 2020, the parties agreed to waive the hearing on the merits. The parties briefed the contested issues in this matter and a proposal for decision was issued in September 2020 recommending a $4.1 million revenue reduction related to non-Advanced Metering System meters included in the DCRF calculation. The parties filed exceptions to the proposal for decision and replies to those exceptions in September 2020. In October 2020 the PUCT issued a final order approving a $16.3 million incremental annual DCRF revenue increase.

In October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020.

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Management's Financial Discussion and Analysis
Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019. In January 2020 the PUCT issued an order approving an unopposed settlement providing for recovery of the requested revenue requirement. Entergy Texas implemented the amended rider beginning with bills covering usage on and after January 23, 2020.

In October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020.

Fuel and purchased power recovery

In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. In March 2020 an intervenor filed testimony proposing that the PUCT disallow: (1) $2 million in replacement power costs associated with generation outages during the reconciliation period; and (2) $24.4 million associated with the operation of the Spindletop natural gas storage facility during the reconciliation period.  In April 2020, Entergy Texas filed rebuttal testimony refuting all points raised by the intervenor. In June 2020 the parties filed a stipulation and settlement agreement, which included a $1.2 million disallowance not associated with any particular issue raised by any party. The PUCT approved the settlement in August 2020.

In July 2020, Entergy Texas filed an application with the PUCT to implement an interim fuel refund of $25.5 million, including interest. Entergy Texas proposes that the interim fuel refund be implemented beginning with the first August 2020 billing cycle over a three-month period for smaller customers and in a lump sum amount in the billing month of August 2020 for transmission-level customers. The interim fuel refund was approved in July 2020, and Entergy Texas began refunds in August 2020.

COVID-19 Orders

In March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of COVID-19. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. While the PUCT moratorium on disconnections has expired, Entergy Texas has not yet resumed disconnections and continues to defer the associated costs. As of September 30, 2020, Entergy Texas recorded a regulatory asset of $8.7 million for costs associated with the COVID-19 pandemic.

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Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Generation Rider

In October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Montgomery County Power Station. In October 2020 the administrative law judge set a procedural schedule that will result in an administrative approval of Entergy Texas’s application in December 2020 if it is unopposed by parties to the proceeding.

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, 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.

Other Postretirement Benefits
As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, Entergy Texas now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $8.9 million.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$494,922 $442,877 $1,206,452 $1,146,931 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale96,902 64,211 186,038 129,285 
Purchased power139,204 151,965 383,346 463,966 
Other operation and maintenance60,423 69,937 179,883 190,989 
Taxes other than income taxes15,642 20,870 55,438 60,773 
Depreciation and amortization45,195 38,722 131,596 113,071 
Other regulatory charges - net29,250 27,662 69,342 66,574 
TOTAL386,616 373,367 1,005,643 1,024,658 
OPERATING INCOME108,306 69,510 200,809 122,273 
OTHER INCOME
Allowance for equity funds used during construction10,875 7,454 33,117 18,948 
Interest and investment income203 486 975 2,542 
Miscellaneous - net2,061 115 924 980 
TOTAL13,139 8,055 35,016 22,470 
INTEREST EXPENSE
Interest expense22,648 21,379 68,643 63,992 
Allowance for borrowed funds used during construction(4,673)(3,534)(14,231)(9,370)
TOTAL17,975 17,845 54,412 54,622 
INCOME BEFORE INCOME TAXES103,470 59,720 181,413 90,121 
Income taxes11,306 (13,504)9,674 (43,381)
NET INCOME92,164 73,224 171,739 133,502 
Preferred dividend requirements470 110 1,411 110 
EARNINGS APPLICABLE TO COMMON STOCK$91,694 $73,114 $170,328 $133,392 
See Notes to Financial Statements.


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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$171,739 $133,502 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization131,596 113,071 
Deferred income taxes, investment tax credits, and non-current taxes accrued37,072 21,898 
Changes in assets and liabilities:
Receivables(55,059)21,578 
Fuel inventory(1,726)(1,476)
Accounts payable15,542 (58,792)
Taxes accrued(12,623)3,545 
Interest accrued(7,855)(11,478)
Deferred fuel costs61,995 (6,588)
Other working capital accounts(8,382)(13,740)
Provisions for estimated losses(69)(3,470)
Other regulatory assets42,904 63,793 
Other regulatory liabilities(39,791)(83,674)
Pension and other postretirement liabilities(18,179)(7,209)
Other assets and liabilities(22,911)3,921 
Net cash flow provided by operating activities294,253 174,881 
INVESTING ACTIVITIES
Construction expenditures(703,650)(622,342)
Allowance for equity funds used during construction33,117 19,029 
Payment for purchase of assets(4,931)— 
Changes in money pool receivable - net11,181 (8,299)
Changes in securitization account6,856 8,535 
Net cash flow used in investing activities(657,427)(603,077)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt344,110 986,477 
Retirement of long-term debt(216,266)(563,246)
Capital contribution from parent175,000 87,500 
Proceeds from issuance of preferred stock— 33,486 
Change in money pool payable - net54,229 (22,389)
Preferred stock dividends paid(1,594)— 
Other(5,200)(1,410)
Net cash flow provided by financing activities350,279 520,418 
Net increase (decrease) in cash and cash equivalents(12,895)92,222 
Cash and cash equivalents at beginning of period12,929 56 
Cash and cash equivalents at end of period$34 $92,278 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$75,129 $73,752 
Income taxes$8,331 $2,292 
See Notes to Financial Statements.
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$34 $25 
Temporary cash investments— 12,904 
Total cash and cash equivalents34 12,929 
Securitization recovery trust account30,864 37,720 
Accounts receivable:
Customer116,531 59,365 
Allowance for doubtful accounts(10,629)(471)
Associated companies17,282 24,001 
Other8,286 17,050 
Accrued unbilled revenues62,401 50,048 
Total accounts receivable193,871 149,993 
Fuel inventory - at average cost49,319 47,593 
Materials and supplies - at average cost50,701 46,056 
Prepayments and other24,624 21,012 
TOTAL349,413 315,303 
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity364 396 
Non-utility property - at cost (less accumulated depreciation)376 376 
Other19,667 20,077 
TOTAL20,407 20,849 
UTILITY PLANT
Electric5,705,892 5,199,027 
Construction work in progress1,003,217 760,354 
TOTAL UTILITY PLANT6,709,109 5,959,381 
Less - accumulated depreciation and amortization1,840,542 1,770,852 
UTILITY PLANT - NET4,868,567 4,188,529 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $98,347 as of September 30, 2020 and $160,375 as of December 31, 2019)
469,744 512,648 
Other62,534 33,393 
TOTAL532,278 546,041 
TOTAL ASSETS$5,770,665 $5,070,722 
See Notes to Financial Statements.  
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$200,000 $— 
Accounts payable:
Associated companies107,21558,055
Other325,265 188,460 
Customer deposits38,755 40,232 
Taxes accrued37,085 49,708 
Interest accrued11,137 18,992 
Current portion of unprotected excess accumulated deferred income taxes28,827 26,552 
Deferred fuel costs74,996 13,001 
Other12,387 10,521 
TOTAL835,667 405,521 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued634,679 585,413 
Accumulated deferred investment tax credits10,096 10,559 
Regulatory liability for income taxes - net189,066 225,980 
Other regulatory liabilities36,933 42,085 
Asset retirement cost liabilities7,952 7,631 
Accumulated provisions8,039 8,108 
Long-term debt (includes securitization bonds of $139,295 as of September 30, 2020 and $205,349 as of December 31, 2019)
1,847,749 1,922,956 
Other55,769 63,062 
TOTAL2,790,283 2,865,794 
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2020 and 2019
49,452 49,452 
Paid-in capital955,162 780,182 
Retained earnings1,105,101 934,773 
Total common shareholder's equity2,109,715 1,764,407 
Preferred stock without sinking fund35,000 35,000 
TOTAL2,144,715 1,799,407 
TOTAL LIABILITIES AND EQUITY$5,770,665 $5,070,722 
See Notes to Financial Statements.
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Common Equity
Preferred StockCommon
Stock		Paid-in
Capital		Retained
Earnings		Total
(In Thousands)
Balance at December 31, 2018$— $49,452 $596,994 $775,956 $1,422,402 
Net income— — — 21,342 21,342 
Balance at March 31, 2019 — 49,452 596,994 797,298 1,443,744 
Net income— — — 38,936 38,936 
Balance at June 30, 2019— 49,452 596,994 836,234 1,482,680 
Net income— — — 73,224 73,224 
Capital contribution from parent— — 87,500 — 87,500 
Preferred stock issuance35,000 — (1,514)— 33,486 
Preferred stock dividends— — — (110)(110)
Balance at September 30, 2019$35,000 $49,452 $682,980 $909,348 $1,676,780 
Balance at December 31, 2019$35,000 $49,452 $780,182 $934,773 $1,799,407 
Net income— — — 32,707 32,707 
Capital contribution from parent— — 175,000 — 175,000 
Preferred stock dividends— — — (470)(470)
Balance at March 31, 202035,000 49,452 955,182 967,010 2,006,644 
Net income— — — 46,868 46,868 
Preferred stock dividends— — — (471)(471)
Other— — (10)— (10)
Balance at June 30, 202035,000 49,452 955,172 1,013,407 2,053,031 
Net income— — — 92,164 92,164 
Preferred stock dividends— — — (470)(470)
Other— — (10)— (10)
Balance at September 30, 2020$35,000 $49,452 $955,162 $1,105,101 $2,144,715 
See Notes to Financial Statements.
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$221 $216 $5 2 
Commercial101 95 6 6 
Industrial93 101 (8)(8)
Governmental6 5 1 20 
Total billed retail421 417 4 1 
Sales for resale:
Associated companies13 14 (1)(7)
Non-associated companies55 2 53 2,650 
Other6 10 (4)(40)
Total$495 $443 $52 12 
Billed Electric Energy Sales (GWh):
Residential2,070 1,994 76 4 
Commercial1,276 1,365 (89)(7)
Industrial2,060 2,219 (159)(7)
Governmental69 69 — — 
Total retail5,475 5,647 (172)(3)
Sales for resale:
Associated companies331 372 (41)(11)
Non-associated companies407 148 259 175 
Total6,213 6,167 46 1 
Nine Months EndedIncrease/
20202019(Decrease)%
(Dollars In Millions)
Electric Operating Revenues:
Residential$514 $510 $4 1 
Commercial269 255 14 5 
Industrial280 279 1 — 
Governmental17 16 1 6 
Total billed retail1,080 1,060 20 2 
Sales for resale:
Associated companies30 42 (12)(29)
Non-associated companies59 6 53 883 
Other37 39 (2)(5)
Total$1,206 $1,147 $59 5 
Billed Electric Energy Sales (GWh):
Residential4,782 4,662 120 3 
Commercial3,309 3,533 (224)(6)
Industrial5,970 5,999 (29)— 
Governmental195 194 1 1 
Total retail14,256 14,388 (132)(1)
Sales for resale:
Associated companies895 1,157 (262)(23)
Non-associated companies717 300 417 139 
Total15,868 15,845 23 — 
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SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


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.

Results of Operations

Net Income

Third Quarter 2020 Compared to Third Quarter 2019

Net income increased $6 million primarily due to the increase in operating revenues resulting from changes in rate base and provisions against revenue recorded in the third quarter 2019 in connection with the return on equity complaint against System Energy. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the return on equity complaint against System Energy.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

Net income increased $15.5 million primarily due to:

•provisions against revenue recorded in 2019 in connection with the return on equity complaint against System Energy. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the return on equity complaint against System Energy;
•the increase in operating revenues resulting from changes in rate base; and
•an increase in the allowance for equity funds used during construction resulting from increased capital spending in 2020 including the scheduled 2020 Grand Gulf refueling outage.

Income Taxes

The effective income tax rate was 22.1% for the third quarter 2020. The difference in the effective income tax rate for the third quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 19.7% for the nine months ended September 30, 2020. The difference in the effective income tax rate for the nine months ended September 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.

The effective income tax rate was 17.3% for the third quarter 2019. The difference in the effective income tax rate for the third quarter 2019 versus the federal statutory rate of 21% was primarily due to 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.
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The effective income tax rate was 11.6% for the nine months ended September 30, 2019. The difference in the effective income tax rate for the nine months ended September 30, 2019 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 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.

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 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 2019, 2018, and 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and 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 the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2020 and 2019 were as follows:
20202019
(In Thousands)
Cash and cash equivalents at beginning of period$68,534 $95,685 
Cash flow provided by (used in):
Operating activities159,300 224,675 
Investing activities(179,267)15,896 
Financing activities(36,636)(171,931)
Net increase (decrease) in cash and cash equivalents(56,603)68,640 
Cash and cash equivalents at end of period$11,931 $164,325 

Operating Activities

Net cash flow provided by operating activities decreased $65.4 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to an increase in spending of $36.9 million on nuclear refueling outages in 2020 as compared to the same period in 2019 and timing of payments to vendors.

Investing Activities

System Energy’s investing activities used $179.3 million of cash for the nine months ended September 30, 2020 compared to providing $15.9 million of cash for the nine months ended September 30, 2019 primarily due to:

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•an increase of $90.3 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;
•an increase of $78.8 million in nuclear construction expenditures as a result of spending in 2020 on Grand Gulf outage projects and upgrades; and
•money pool activity.

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 $58.3 million for the nine months ended September 30, 2020 compared to decreasing by $92.3 million for the nine months ended September 30, 2019. 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 used in financing activities decreased by $135.3 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to the following activity:

•net long-term borrowings of $44.1 million in 2020 compared to net repayments of long-term borrowings of $60.3 million in 2019 on the nuclear fuel company variable interest entity’s credit facility; and
•a decrease of $29.8 million in common stock dividends and distributions in 2020 in order to maintain System Energy’s capital structure.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to borrowings in 2020 on the nuclear fuel company variable interest entity’s credit facility.
 September 30,
2020		December 31,
2019
Debt to capital45.1 %43.5 %
Effect of subtracting cash(0.5 %)(3.3 %)
Net debt to net capital44.6 %40.2 %

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.

System Energy seeks to optimize its capital structure in accordance with its regulatory requirements and to control its cost of capital while also maintaining equity capitalization at a level consistent with investment-grade debt ratings. To the extent that operating cash flows are in excess of planned investments, cash may be used to reduce outstanding debt or may be paid as a dividend, or both, in appropriate amounts to maintain the capital structure.  To the extent that operating cash flows are insufficient to support planned investments, System Energy may issue incremental debt or reduce dividends, or both, to maintain its capital structure. In addition, System Energy may receive equity contributions to maintain its capital structure for certain circumstances that would materially alter the capital structure if financed entirely with debt and reduced dividends.

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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 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 2021 through 2023 and currently anticipates making $430 million in capital investments during that period. The preliminary estimate includes amounts associated with specific investments and initiatives such as investments in Grand Gulf.

System Energy’s receivables from the money pool were as follows:
September 30,
2020		December 31,
2019		September 30,
2019		December 31,
2018
(In Thousands)
$1,021$59,298$14,775$107,122

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 September 2022. As of September 30, 2020, $75.7 million in loans 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.

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 and Capital Structure Complaints

As discussed in the Form 10-K, in November 2019, in a proceeding that did not involve System Energy, the FERC issued an order addressing the methodology for determining the return on equity applicable to transmission owners in MISO. Thereafter, the participants in the System Energy proceeding agreed to amend the procedural schedule to allow the participants to file supplemental testimony addressing the order in the MISO transmission owner proceeding (Opinion No. 569).

In February 2020 the LPSC, the MPSC and APSC, and the FERC trial staff filed supplemental testimony addressing Opinion No. 569 and how it would affect the return on equity evaluation for the two complaint periods concerning System Energy. For the first refund period, based on their respective interpretations and applications of the Opinion No. 569 methodology, the LPSC argues for an authorized return on equity for System Energy of 8.44%; the MPSC and APSC argue for an authorized return on equity of 8.41%; and the FERC trial staff argues for an authorized return on equity of 9.22%. For the second refund period and on a prospective basis, based on their respective interpretations and applications of the Opinion No. 569 methodology, the LPSC argues for an authorized return on equity for System Energy of 7.89%; the MPSC and APSC argue that an authorized return on equity of 8.01% may be appropriate; and the FERC trial staff argues for an authorized return on equity of 8.66%.

In April 2020, System Energy filed supplemental answering testimony addressing Opinion No. 569. System Energy argues that the Opinion No. 569 methodology is conceptually and analytically defective for
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purposes of establishing just and reasonable authorized return on equity determinations and proposes an alternative approach. As its primary recommendation, System Energy continues to support the return on equity determinations in its March 2019 testimony for the first refund period and its June 2019 testimony for the second refund period. Under the Opinion No. 569 methodology, System Energy calculates a “presumptively just and reasonable range” for the authorized return on equity for the first refund period of 8.57% to 9.52%, and for the second refund period of 8.28% to 9.11%. System Energy argues that these ranges are not just and reasonable results. Under its proposed alternative methodology, System Energy calculates an authorized return on equity of 10.26% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively.

In May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule was further revised in order to allow parties to the System Energy proceeding to address the Opinion No. 569-A methodology. Pursuant to the revised schedule, in June 2020, the LPSC, the MPSC and APSC, and the FERC trial staff filed supplemental testimony addressing Opinion No. 569-A and how it would affect the return on equity evaluation for the two complaint periods concerning System Energy. For the first refund period, based on their respective interpretations and applications of the Opinion No. 569-A methodology, the LPSC argues for an authorized return on equity for System Energy of 7.97%; the MPSC and APSC argue for an authorized return on equity of 9.24%; and the FERC trial staff argues for an authorized return on equity of 9.49%. For the second refund period and on a prospective basis, based on their respective interpretations and applications of the Opinion No. 569-A methodology, the LPSC argues for an authorized return on equity for System Energy of 7.78%; the MPSC and APSC argue that an authorized return on equity of 9.15% may be appropriate if the second complaint is not dismissed; and the FERC trial staff argues for an authorized return on equity of 9.09% if the second complaint is not dismissed.

Pursuant to the revised procedural schedule, in July 2020, System Energy filed supplemental testimony addressing Opinion No. 569-A. System Energy argues that strict application of the Opinion No. 569-A methodology produces results inconsistent with investor requirements and does not provide a sound basis on which to evaluate System Energy’s authorized return on equity. As its primary recommendation, System Energy argues for the use of a methodology that incorporates four separate financial models, including the constant growth form of the discounted cash flow model and the empirical capital asset pricing model. Based on application of its recommended methodology, System Energy argues for an authorized return on equity of 10.12% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively. Under the Opinion No. 569-A methodology, System Energy calculates an authorized return on equity of 9.44% for the first refund period, which also falls within the presumptively just and reasonable range calculated for the second refund period and prospectively.

The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing occurred in late-September through early-October 2020, and the initial decision is due in February 2021.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony sought refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions, and the cost of capital additions associated with the sale-leaseback interest, as well as interest on those amounts.

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In June 2019 System Energy filed answering testimony arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save costs over the initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties.

In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for the liabilities associated with uncertain tax positions. The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable, but explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement re-billing calculation. Adjustments to depreciation expense in any re-billing under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for the liabilities associated with uncertain tax positions.  The LPSC seeks approximately $512 million, plus interest, which is approximately $185 million through September 30, 2020.  The FERC trial staff also filed rebuttal testimony in which it seeks refunds of a similar amount as the LPSC for the liabilities associated with uncertain tax positions.  The LPSC testimony also argued that adjustments to depreciation rates should affect rate base on a prospective basis only.

A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through September 30, 2020, is approximately $422 million, plus interest, which is approximately $106 million through September 30, 2020. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through September 30, 2020.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. In June 2020, System Energy, the LPSC, and the FERC trial staff filed briefs on exceptions, challenging several of the initial decision’s findings. System Energy’s brief on exceptions challenged the initial decision’s limitations on recovery of the lease renewal payments, its proposed rate base refund for the liabilities associated with uncertain tax positions, and its proposal to asymmetrically treat interest on bill corrections for depreciation expense adjustments. The LPSC’s and the FERC trial staff’s briefs on exceptions each challenged the initial decision’s allowance for recovery of the cost of service associated with the
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lease renewal based on the remaining net book value of the leased assets, its calculation of the remaining net book value of the leased assets, and the amount of the initial decision’s proposed rate base refund for the liabilities associated with uncertain tax positions. The LPSC’s brief on exceptions also challenged the initial decision’s proposal that depreciation expense adjustments include retroactive adjustments to rate base and its finding that section 203 of the Federal Power Act did not apply to the lease renewal. The FERC trial staff’s brief on exceptions also challenged the initial decision’s finding that the FERC need not institute a formal investigation into System Energy’s tariff. In October 2020, System Energy, the LPSC, the MPSC, the APSC, and the City Council filed briefs opposing exceptions. System Energy opposed the exceptions filed by the LPSC and the FERC trial staff. The LPSC, MPSC, APSC, City Council, and the FERC trial staff opposed the exceptions filed by System Energy. Also in October 2020 the MPSC, APSC, and the City Council filed briefs adopting the exceptions of the LPSC and the FERC trial staff. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

In addition, in September 2020, the IRS issued a Notice of Proposed Adjustment (NOPA) and an Entergy executed it. The NOPA memorializes the IRS’s decision to adjust the 2015 consolidated federal income tax return of Entergy Corporation and certain of its subsidiaries, including System Energy, with regard to the uncertain decommissioning tax position. Pursuant to the audit resolution documented in the NOPA, the IRS allowed System Energy’s inclusion of $102 million of future nuclear decommissioning costs in System Energy’s cost of goods sold for the 2015 tax year, roughly 10% of the requested deduction, but disallowed the balance of the position. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020, the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA issued by the IRS in September 2020, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at FERC to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position. On a prospective basis beginning with the October 2020 bill, System Energy proposes to include the accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position as a credit to rate base under the Unit Power Sales Agreement. Comments, protests, and interventions in this filing are due in November 2020.

LPSC Authorization of Additional Complaints

In May 2020 the LPSC authorized its staff to file additional complaints at FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigation of rates charged by System Energy. The LPSC directive authorizes its staff to file complaints at FERC “necessary to address these rate issues, to request a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The new complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. Several of the filed rate allegations overlap with the previous complaints. The filed rate allegations not previously raised are that System Energy: failed to provide a rate base credit to customers for the
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“time value” of sale-leaseback lease payments collected from customers in advance of the time those payments were due to the owner-lessors; improperly included certain lease refinancing costs in rate base as prepayments; improperly included nuclear decommissioning outage costs in rate base; failed to include categories of accumulated deferred income taxes as a reduction to rate base; charged customers based on a higher equity ratio than would be appropriate due to excessive retained earnings; and did not correctly reflect money pool investments and imprudently invested cash into the money pool. The elements of the Unit Power Sales Agreement that the complaint alleges are unjust and unreasonable include: incentive and executive compensation, lack of an equity re-opener, lobbying, and private airplane travel. The new complaint also requests a rate investigation into the Unit Power Sales Agreement and System Energy’s billing practices pursuant to Section 206 of the Federal Power Act, including any issue relevant to the Unit Power Sales Agreement and its inputs. System Energy will file its answer opposing the new complaint in November 2020.

The operational prudence-related complaint has not been filed as of this date, and the LPSC directive did not set a date for the filing.

Nuclear Matters

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

NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs. Grand Gulf is currently in Column 1, but is expected to be placed in Column 2 by the NRC based on the incidence of unplanned plant scrams during the third quarter of 2020.

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. The following is an update to that discussion.

Other Postretirement Benefits
As described in Note 6 to the financial statements herein, in March 2020, Entergy announced changes to its other postretirement benefits. As a result, System Energy now expects 2020 other postretirement health care and life insurance benefit income, including amounts capitalized, of $1.5 million.
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New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.
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SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Three Months EndedNine Months Ended
2020201920202019
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$148,517 $145,472 $405,230 $424,585 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale13,620 23,748 32,771 66,335 
Nuclear refueling outage expenses6,942 8,412 20,880 25,013 
Other operation and maintenance48,902 49,533 132,175 147,283 
Decommissioning9,341 8,976 27,746 26,663 
Taxes other than income taxes7,203 7,120 22,281 21,835 
Depreciation and amortization28,006 26,613 82,406 79,761 
Other regulatory credits - net(14,393)(8,016)(28,470)(27,059)
TOTAL99,621 116,386 289,789 339,831 
OPERATING INCOME 48,896 29,086 115,441 84,754 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction1,206 2,251 7,990 5,518 
Interest and investment income1,303 8,215 18,749 21,577 
Miscellaneous - net(3,354)(1,300)(7,971)(4,018)
TOTAL(845)9,166 18,768 23,077 
INTEREST EXPENSE
Interest expense8,427 8,546 25,501 26,467 
Allowance for borrowed funds used during construction(240)(551)(1,585)(1,350)
TOTAL8,187 7,995 23,916 25,117 
INCOME BEFORE INCOME TAXES39,864 30,257 110,293 82,714 
Income taxes8,800 5,226 21,725 9,633 
NET INCOME$31,064 $25,031 $88,568 $73,081 
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
20202019
(In Thousands)
OPERATING ACTIVITIES
Net income$88,568 $73,081 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization137,201 163,069 
Deferred income taxes, investment tax credits, and non-current taxes accrued(272,383)(2,426)
Changes in assets and liabilities:
Receivables15,637 (7,456)
Accounts payable(19,775)2,935 
Prepaid taxes and taxes accrued431,677 14,579 
Interest accrued(188)(1,478)
Other working capital accounts(40,566)3,411 
Other regulatory assets(25,956)(9,121)
Other regulatory liabilities45,647 90,118 
Pension and other postretirement liabilities(11,033)(5,013)
Other assets and liabilities(189,529)(97,024)
Net cash flow provided by operating activities159,300 224,675 
INVESTING ACTIVITIES
Construction expenditures(169,475)(92,228)
Allowance for equity funds used during construction7,990 5,518 
Nuclear fuel purchases(85,483)(2,046)
Proceeds from the sale of nuclear fuel19,444 26,272 
Proceeds from nuclear decommissioning trust fund sales322,982 348,606 
Investment in nuclear decommissioning trust funds(333,002)(362,573)
Changes in money pool receivable - net58,277 92,347 
Net cash flow provided by (used in) investing activities(179,267)15,896 
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt859,727 1,007,775 
Retirement of long-term debt(815,710)(1,069,206)
Common stock dividends and distributions paid(80,653)(110,500)
Net cash flow used in financing activities(36,636)(171,931)
Net increase (decrease) in cash and cash equivalents(56,603)68,640 
Cash and cash equivalents at beginning of period68,534 95,685 
Cash and cash equivalents at end of period$11,931 $164,325 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$17,178 $21,052 
Income taxes($4,000)$— 
See Notes to Financial Statements.
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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$118 $93 
Temporary cash investments11,813 68,441 
Total cash and cash equivalents11,931 68,534 
Accounts receivable:
Associated companies51,524 121,972 
Other4,081 7,547 
Total accounts receivable55,605 129,519 
Materials and supplies - at average cost120,921 108,766 
Deferred nuclear refueling outage costs41,225 14,493 
Prepayments and other7,722 6,045 
TOTAL237,404 327,357 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,114,508 1,054,098 
TOTAL1,114,508 1,054,098 
UTILITY PLANT
Electric5,291,882 5,070,859 
Construction work in progress53,959 164,996 
Nuclear fuel185,314 149,574 
TOTAL UTILITY PLANT5,531,155 5,385,429 
Less - accumulated depreciation and amortization3,329,347 3,285,487 
UTILITY PLANT - NET2,201,808 2,099,942 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets516,039 490,083 
Accumulated deferred income tax— 8,023 
Other3,142 3,192 
TOTAL519,181 501,298 
TOTAL ASSETS$4,072,901 $3,982,695 
See Notes to Financial Statements.
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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2020 and December 31, 2019
(Unaudited)
20202019
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$100,015 $10 
Accounts payable:
Associated companies13,440 14,619 
Other35,222 64,144 
Taxes accrued445,509 13,832 
Interest accrued11,805 11,993 
Other3,379 3,381 
TOTAL609,370 107,979 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued395,806 821,963 
Accumulated deferred investment tax credits39,222 40,181 
Regulatory liability for income taxes - net151,606 142,845 
Other regulatory liabilities570,301 533,415 
Decommissioning959,476 931,729 
Pension and other postretirement liabilities98,783 109,816 
Long-term debt492,596 548,097 
Other35,758 34,602 
TOTAL2,743,548 3,162,648 
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350
    shares in 2020 and 2019
601,850 601,850 
Retained earnings118,133 110,218 
TOTAL719,983 712,068 
TOTAL LIABILITIES AND EQUITY$4,072,901 $3,982,695 
See Notes to Financial Statements.
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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2020 and 2019
(Unaudited)
Common Equity
Common
Stock		Retained
Earnings		Total
(In Thousands)
Balance at December 31, 2018$601,850 $135,348 $737,198 
Net income— 23,578 23,578 
Common stock dividends and distributions— (45,500)(45,500)
Balance at March 31, 2019601,850 113,426 715,276 
Net income— 24,472 24,472 
Common stock dividends and distributions— (42,500)(42,500)
Balance at June 30, 2019601,850 95,398 697,248 
Net income— 25,031 25,031 
Common stock dividends and distributions— (22,500)(22,500)
Balance at September 30, 2019$601,850 $97,929 $699,779 
Balance at December 31, 2019$601,850 $110,218 $712,068 
Net income— 28,513 28,513 
Common stock dividends and distributions— (13,653)(13,653)
Balance at March 31, 2020601,850 125,078 726,928 
Net income— 28,991 28,991 
Common stock dividends and distributions— (46,000)(46,000)
Balance at June 30, 2020601,850 108,069 709,919 
Net income— 31,064 31,064 
Common stock dividends and distributions— (21,000)(21,000)
Balance at September 30, 2020$601,850 $118,133 $719,983 
See Notes to Financial Statements.

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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 Notes 1 and 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

See the risk factors discussed in “Part I, Item 1A. Risk Factors” in the Form 10-K, which could materially affect Entergy’s and its Registrant Subsidiaries’ business, financial condition, or future results. The information set forth in this report, including the risk factor presented below, updates and should be read in conjunction with the risk factors and information disclosed in the Form 10-K. In addition, because Entergy cannot predict the ultimate impacts of COVID-19, the actual impacts may also exacerbate other risks discussed in “Item 1A. Risk Factors” in the Form 10-K, any of which could have a material effect on Entergy and its Registrant Subsidiaries. The situation remains fluid and while Entergy and its Utility operating companies have not incurred significant disruptions thus far from the COVID-19 global pandemic, the likelihood of an adverse impact could increase the longer the global pandemic persists.

(Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

The impacts of the COVID-19 outbreak and responsive measures taken on Entergy’s and its Utility operating companies’ business, results of operations, and financial condition are highly uncertain and cannot be predicted.

In December 2019, a novel strain of coronavirus was reported to have surfaced in Wuhan, China. Since then, COVID-19 has spread throughout most countries in the world, including the United States.  Public health officials in the United States have both recommended and mandated wearing of masks, precautions to mitigate the spread of COVID-19, including prohibitions on congregating in heavily-populated areas, mandated closure or limitations on the functions of non-essential business, and shelter-in-place orders or similar measures, including throughout Entergy’s service areas. While some of these mitigation measures have been lifted, it is unclear how long certain forms of mitigation measures will remain in place, whether they will be reinstated in the future, and how they will ultimately impact the general economy, Entergy’s customers, and its operations.

Entergy and its Utility operating companies have experienced a decline in commercial and industrial sales and an increase in late payments by customers, and expect such reduced levels of sales and delays in customer payments to continue, the extent and duration of which management cannot predict.  The Utility operating companies temporarily suspended disconnecting customers for non-payment of bills. While they are working with regulators to ensure ultimate recovery for those and other COVID-19 related costs, such recovery cannot be guaranteed.  Entergy and its Registrant Subsidiaries also could experience, and in some cases have experienced, among other challenges, supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; delays in regulatory proceedings; workforce availability, health or safety issues; increased storm recovery costs; increased cybersecurity risks as a result of many employees telecommuting; increased late or uncollectible customer payments; volatility in the credit or capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available credit facilities); or other adverse impacts on their ability to execute on business strategies and initiatives.
A sustained or further economic decline could adversely impact Entergy’s and the Utility operating companies’ liquidity and cash flows, including through declining sales, reduced revenues, delays in receipts of customer payments, or increased bad debt expense. In addition, if the pandemic continues to create disruptions or
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turmoil in the credit or financial markets, or adversely impacts Entergy’s credit metrics or ratings, such developments could adversely affect its ability to access capital on favorable terms and continue to meet its liquidity needs, or cause a decrease in the value of its defined benefit pension trust funds, as well as its nuclear decommissioning trust funds, all of which are highly uncertain and cannot be predicted.

Entergy cannot predict the extent or duration of the outbreak, the timing or effectiveness of a vaccine, anti-viral or other treatments for COVID-19, governmental responsive measures, or the extent of the effects or ultimate impacts on the global, national or local economy, the capital markets, or its customers, suppliers, operations, financial condition, results of operations, or cash flows.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (a)
PeriodTotal 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)
7/01/2020-7/31/2020— $— — $350,052,918 
8/01/2020-8/31/2020— $— — $350,052,918 
9/01/2020-9/30/2020— $— — $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 2020, Entergy withheld 151,159 shares of its common stock at $126.31 per share, 79,153 shares of its common stock at $129.55 per share, 41,167 shares of its common stock at $131.52 per share, 2,269 shares of its common stock at $124.28 per share, 1,331 shares of its common stock at $123.74 per share, 1,088 shares of its common stock at $102.93 per share, 441 shares of its common stock at $132.19 per share, 71 shares of its common stock at $86.51 per share, 31 shares of its common stock at $115.90 per share, and 19 shares of its common stock at $86.74 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 is an update to the “Regulation of the Nuclear Power Industry” section of Part I, Item 1 of the Form 10-K.
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Nuclear Waste Policy Act of 1982

Nuclear Plant Decommissioning

In March 2020 filings with the NRC were made reporting on decommissioning funding for all of Entergy subsidiaries’ nuclear plants.  Those reports showed that decommissioning funding for each of the nuclear plants met the NRC’s financial assurance requirements.

Environmental Regulation

Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.

National Ambient Air Quality Standards

See the Form 10-K for discussion of the National Ambient Air Quality Standards set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

Potential SO2 Nonattainment

The EPA issued a final rule in June 2010 adopting an SO2 1-hour national ambient air quality standard of 75 parts per billion. In Entergy’s utility service territory, only St. Bernard Parish and Evangeline Parish in Louisiana are designated as nonattainment. In August 2017 the EPA issued a letter indicating that East Baton Rouge and St. Charles parishes would be designated by December 31, 2020, as monitors were installed to determine compliance. In August 2020 the EPA published and sought public comment on its intent to designate East Baton Rouge, St. Charles, St. James, and West Baton Rouge parishes in Louisiana as attainment/unclassifiable, and, in Texas, Jefferson County as attainment/unclassifiable and Orange County as unclassifiable. Final designations are expected to be made by December 31, 2020. Entergy continues to monitor this situation.

Hazardous Air Pollutants

As discussed in the Form 10-K, the EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011, which had a compliance date, with a widely granted one-year extension, of April 2016. The required controls have been installed and are operational at all affected Entergy units. In May 2020 the EPA finalized a rule that finds that it is not “appropriate and necessary” to regulate hazardous air pollutants from electric steam generating units under the provisions of section 112(n) of the Clean Air Act. This is a reversal of the EPA’s previous finding requiring such regulation. The final appropriate and necessary finding does not revise the underlying MATS rule. Several lawsuits have been filed challenging the appropriate and necessary finding. Entergy will continue to monitor this situation.

Regional Haze

As discussed in the Form 10-K, in Louisiana, Entergy has worked with the Louisiana Department of Environmental Quality (LDEQ) and the EPA to revise the Louisiana state implementation plan (SIP) for regional haze, which had been disapproved in part in 2012. The LDEQ submitted a revised SIP in February 2017. In May 2017 the EPA proposed to approve a majority of the revisions. In September 2017 the EPA issued a proposed SIP approval for the Nelson plant, requiring an emission limitation consistent with the use of low-sulfur coal, with a compliance date of January 22, 2021. The EPA issued final approval in December 2017. The EPA approval was appealed to the U.S. Court of Appeals for the Fifth Circuit. In October 2019 the Fifth Circuit affirmed the EPA’s SIP approval. A petition for rehearing filed by plaintiffs was denied by the Fifth Circuit. Plaintiffs did not petition for further review by the Supreme Court.

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The second planning period (2018-2028) for the regional haze program requires states to examine sources for impacts on visibility and to prepare SIPs by 2021. Entergy has received information collection requests from Arkansas and Louisiana requesting an evaluation of technical and economic feasibility of various NOx and SO2 control technologies for Independence, Nelson 6, and Ninemile. Responses to the information requests have been submitted to the respective state agencies.

New and Existing Source Performance Standards for Greenhouse Gas Emissions

In July 2019 the EPA released the Affordable Clean Energy Rule (ACE), which applies only to existing coal-fired electric generating units. The ACE determines that heat rate improvements are the best system of emission reductions and lists six candidate technologies for consideration by states at each coal unit. The rule and associated rulemakings by the EPA replace the Obama administration’s Clean Power Plan rule. The ACE rule provides states discretion in determining how the best system for emission reductions applies to individual units, including through the consideration of technical feasibility and the remaining useful life of the facility. Arkansas and Louisiana have issued information collection requests to Entergy facilities to help the states collect the information needed to determine the best system of emission reductions for each facility. Entergy responded to the request and will continue to monitor litigation challenging the rule. The EPA also has proposed a revision to the new source performance standard on greenhouse gas emissions that primarily impacts new coal units and, therefore, should not impact Entergy.

Potential Legislative, Regulatory, and Judicial Developments

As discussed in the Form 10-K, Entergy continues to support national legislation that would increase planning certainty for electric utilities while addressing carbon dioxide emissions in a responsible and flexible manner. In September 2020, Entergy committed to achieving net-zero carbon emissions by 2050, while continuing its commitment to grid reliability and affordability for customers. Technology research and development, innovation, and advancement are critical to Entergy’s ability to meet this climate commitment.

Coal Combustion Residuals

As discussed in the Form 10-K, in late-2017, Entergy determined that certain in-ground wastewater treatment system recycle ponds at its White Bluff and Independence facilities require management under EPA regulations. In order to meet these regulations, one of two recycle ponds at White Bluff commenced closure in October 2018. Additionally, Entergy anticipates commencing closure of the remaining recycle pond at White Bluff and both recycle ponds at Independence in the fourth quarter of 2020.

Item 6.  Exhibits
4(a) -
4(b) -
4(c) -
*31(a) -
*31(b) -
*31(c) -
*31(d) -
*31(e) -
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*31(f) -
*31(g) -
*31(h) -
*31(i) -
*31(j) -
*31(k) -
*31(l) -
*31(m) -
*31(n) -
**32(a) -
**32(b) -
**32(c) -
**32(d) -
**32(e) -
**32(f) -
**32(g) -
**32(h) -
**32(i) -
**32(j) -
**32(k) -
**32(l) -
**32(m) -
**32(n) -
*101 INS -
Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101 SCH -
Inline XBRL Schema Document.
*101 PRE -
Inline XBRL Presentation Linkbase Document.
*101 LAB -
Inline XBRL Label Linkbase Document.
*101 CAL -
Inline XBRL Calculation Linkbase Document.
*101 DEF -
Inline XBRL Definition Linkbase Document.
*104 -
Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibits 101).
___________________________
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.
**Furnished, not filed, herewith.
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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, LLC
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, LLC
ENTERGY NEW ORLEANS, LLC
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC.
/s/ Kimberly A. Fontan
Kimberly A. Fontan
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

Date:    November 4, 2020

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