Companies: 10,652     total market cap: $140.320 T
โ‚ฌEUR๐Ÿ‡ช๐Ÿ‡บโ‚นINR๐Ÿ‡ฎ๐Ÿ‡ณยฃGBP๐Ÿ‡ฌ๐Ÿ‡ง$CAD๐Ÿ‡จ๐Ÿ‡ฆ$AUD๐Ÿ‡ฆ๐Ÿ‡บ$NZD๐Ÿ‡ณ๐Ÿ‡ฟ$HKD๐Ÿ‡ญ๐Ÿ‡ฐ$SGD๐Ÿ‡ธ๐Ÿ‡ฌ
Entergy
ETR
#558
Rank
$43.48 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
$97.36
Share price
1.96%
Change (1 day)
21.22%
Change (1 year)
๐Ÿ”‹ Electricity๐Ÿšฐ Utility companies โšก Energy
Categories
  1. Entergy
  2. Quarterly Reports (10-Q)
  3. Financial Year FY2021 Q3

Entergy - 10-Q quarterly report FY2021 Q3


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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, 2021
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
__________________________________________________________________________________________





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, 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



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 29, 2021
Entergy Corporation($0.01 par value)200,981,298

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, 2020 and the Quarterly Reports on Form 10-Q for the quarters ended March 31, 2021 and June 30, 2021, filed by the individual registrants with the SEC, and should be read in conjunction therewith.




TABLE OF CONTENTS
Page Number
iii
v
Part I. Financial Information
Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis
1
Consolidated Income Statements
24
Consolidated Statements of Comprehensive Income
25
Consolidated Statements of Cash Flows
26
Consolidated Balance Sheets
28
Consolidated Statements of Changes in Equity
30
Notes to Financial Statements
Note 1. Commitments and Contingencies
32
Note 2. Rate and Regulatory Matters
33
Note 3. Equity
47
Note 4. Revolving Credit Facilities, Lines of Credit, Short-term Borrowings, and Long-term Debt
56
Note 5. Stock-based Compensation
61
Note 6. Retirement and Other Postretirement Benefits
62
Note 7. Business Segment Information
70
Note 8. Risk Management and Fair Values
73
Note 9. Decommissioning Trust Funds
91
Note 10. Income Taxes
98
Note 11. Property, Plant, and Equipment
98
Note 12. Variable Interest Entities
99
Note 13. Revenue
99
Note 14. Acquisitions and Dispositions
103
104
104
Entergy Arkansas, LLC and Subsidiaries
Management’s Financial Discussion and Analysis
105
Consolidated Income Statements
117
Consolidated Statements of Cash Flows
119
Consolidated Balance Sheets
120
Consolidated Statements of Changes in Member’s Equity
122
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis
123
Consolidated Income Statements
137
i
TABLE OF CONTENTS
Page Number
Consolidated Statements of Comprehensive Income
138
Consolidated Statements of Cash Flows
139
Consolidated Balance Sheets
140
Consolidated Statements of Changes in Equity
142
Entergy Mississippi, LLC
Management’s Financial Discussion and Analysis
143
Income Statements
152
Statements of Cash Flows
153
Balance Sheets
154
Statements of Changes in Member’s Equity
156
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis
157
Consolidated Income Statements
167
Consolidated Statements of Cash Flows
169
Consolidated Balance Sheets
170
Consolidated Statements of Changes in Member’s Equity
172
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis
173
Consolidated Income Statements
185
Consolidated Statements of Cash Flows
187
Consolidated Balance Sheets
188
Consolidated Statements of Changes in Equity
190
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis
191
Income Statements
198
Statements of Cash Flows
199
Balance Sheets
200
Statements of Changes in Common Equity
202
Part II. Other Information
203
203
205
205
208
211
ii
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, projections, 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 and related litigation, 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, as well as delays in cost recovery resulting from these proceedings;
•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 and current and potential future claims brought by retail regulators against System Energy Resources, Inc.;
•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 owned or operated nuclear generating facilities and nuclear materials and fuel, including with respect to the planned shutdown and sale of Palisades, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and 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;

iii

FORWARD-LOOKING INFORMATION (Continued)

•Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;
•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, Hurricane Zeta, and Hurricane Ida), 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 events and circumstances that could influence economic conditions in those areas, including power prices, and the risk that anticipated load growth may not materialize;
•changes to federal income tax laws and regulations, including continued impact of 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;
iv

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 aggregate carbon emissions, including its commitment to achieve net-zero carbon emissions by 2050, 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 shutdown and sale of 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.

v

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, 2020 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
vi

DEFINITIONS (Continued)
Abbreviation or AcronymTerm
Indian Point 2
Unit 2 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2020 and was sold in May 2021
Indian Point 3
Unit 3 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2021 and was sold in May 2021
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
vii

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
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
viii
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 shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown of Palisades, the only remaining plant in Entergy Wholesale Commodities’ merchant nuclear fleet.

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

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic and its effects on Entergy’s business.

Hurricane Ida

In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida are currently estimated to be in the range of $2.1 billion to $2.5 billion. Most of the storm costs were incurred by Entergy Louisiana and Entergy New Orleans. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.

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 $850 million and construction work in progress of approximately $1.3 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.

Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of approximately $1 billion of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.
1
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of the Utility’s service territories in Louisiana, including New Orleans, Texas, and to a lesser extent, in Arkansas and Mississippi. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana, Entergy New Orleans, and Entergy Texas.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for February 2021 for Entergy were approximately $720 million, including $145 million for Entergy Arkansas, $285 million for Entergy Louisiana, $65 million for Entergy Mississippi, $35 million for Entergy New Orleans, and $185 million for Entergy Texas. This compares to fuel and purchased power costs for February 2020 for Entergy of $245 million, including $40 million for Entergy Arkansas, $95 million for Entergy Louisiana, $35 million for Entergy Mississippi, $25 million for Entergy New Orleans, and $50 million for Entergy Texas. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana and Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at the Utility operating companies.

2
Table of Contents
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Results of Operations

Third Quarter 2021 Compared to Third Quarter 2020

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the third quarter 2021 to the third quarter 2020 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)
2020 Net Income (Loss) Attributable to Entergy Corporation$551,550 $30,226 ($60,657)$521,119 
Operating revenues502,054 (52,096)6 449,964 
Fuel, fuel-related expenses, and gas purchased for resale306,047 10,063 7 316,117 
Purchased power52,926 (6,511)(7)46,408 
Other regulatory charges (credits) - net97,704 — — 97,704 
Other operation and maintenance11,658 (62,748)348 (50,742)
Asset write-offs, impairments, and related charges— (4,600)— (4,600)
Taxes other than income taxes18,777 (7,833)(22)10,922 
Depreciation and amortization32,089 (11,935)13 20,167 
Other income (deductions)60,195 (78,267)(291)(18,363)
Interest expense7,768 (2,125)7,126 12,769 
Other expenses614 (36,480)— (35,866)
Income taxes15,850 (3,485)(3,527)8,838 
2021 Net Income (Loss) Attributable to Entergy Corporation$570,366 $25,517 ($64,880)$531,003 

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

Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the third quarter 2021 to the third quarter 2020:
Amount
(In Millions)
2020 operating revenues$2,689 
Fuel, rider, and other revenues that do not significantly affect net income392 
Retail electric price133 
Volume/weather(23)
2021 operating revenues$3,191 

3
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis

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 retail electric price variance is primarily due to:

•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of May 2021;
•increases in Entergy Louisiana’s overall formula rate plan revenues, including an increase in the transmission recovery mechanism effective September 2020, an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center, and an increase in formula rate plan revenues implemented with the first billing cycle of September 2021;
•increases in Entergy Mississippi’s formula rate plan rates effective with the first billing cycles of April 2021 and July 2021;
•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020; and
•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and increases in the distribution cost recovery factor rider effective October 2020 and March 2021, each at Entergy Texas.

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

The volume/weather variance is primarily due to a decrease in usage during the unbilled sales period, a decrease in usage from residential customers, and the effect of less favorable weather on residential and commercial sales, partially offset by an increase in industrial usage. The decrease in residential usage was primarily due to the effects of Hurricane Ida in the third quarter 2021 and due to the impact that the COVID-19 pandemic had on prior year usage, partially offset by the effects of Hurricane Laura in the third quarter 2020. The increase in industrial usage was primarily due to an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries, an increase in demand from existing customers, primarily in the gases and chemicals industries as a result of prior year temporary plant shutdowns and operational issues, and an increase in demand from mid-to-small and cogeneration customers. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the impacts from the storms. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the COVID-19 pandemic.

4
Table of Contents
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Billed electric energy sales for Utility for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential11,218 11,634 (4)
Commercial7,795 7,791 — 
Industrial13,187 11,994 10 
Governmental660 660 — 
Total retail32,860 32,079 2 
Sales for resale4,350 4,881 (11)
Total37,210 36,960 1 

See Note 13 to the financial statements herein for additional discussion of operating revenues.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $214 million for the third quarter 2020 to $162 million for the third quarter 2021 primarily due to the shutdown of Indian Point 3 in April 2021.

Following are key performance measures for Entergy Wholesale Commodities for the third quarters 2021 and 2020:
20212020
Owned capacity (MW) (a)1,2052,246
GWh billed2,1664,332
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor97%83%
GWh billed1,7023,943
Average energy price ($/MWh)$69.35$39.51
Average capacity price ($/kW-month)$0.15$3.62
Refueling outage days:
Palisades—32

(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $632 million for the third quarter 2020 to $644 million for the third quarter 2021 primarily due to:

•an increase of $10 million in distribution operations expenses primarily due to higher contractor costs and higher reliability costs;
5
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis

•an increase of $9 million in non-nuclear generation expenses primarily due to higher contract costs, higher materials and supplies costs, and higher expenses associated with plants placed in service, including the Washington Parish Energy Center, purchased in November 2020, and the Montgomery County Power Station, which began commercial operation in January 2021; and
•an increase of $8 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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.

The increase was partially offset by a gain of $15 million, recorded in the third quarter 2021, on the sale of a pipeline.

Taxes other than income taxes increased primarily due to increases in franchise taxes and increases in ad valorem taxes resulting from higher assessments.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station.

Other regulatory charges (credits) - net includes regulatory credits of $14 million, recorded in the third quarter 2020 at Entergy Arkansas, to reflect the 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. Entergy records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and trust earnings plus asset retirement obligation related costs collected in revenue. Entergy Arkansas recorded regulatory charges in the third quarter 2021 as a result of portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds.

Other income increased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of certain of the decommissioning trust funds in the third quarter 2021.

Interest expense increased primarily due to:

•the issuances by Entergy Louisiana of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;
•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;
•the issuance by Entergy Mississippi of $200 million of 3.50% Series mortgage bonds in March 2021; and
•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project.

The increase was partially offset by the repayments by Entergy Louisiana of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.
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Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $114 million for the third quarter 2020 to $51 million for the third quarter 2021 primarily due to:

•a decrease of $49 million primarily resulting from the absence of expenses from Indian Point 3, after it was shut down in April 2021; and
•a decrease of $15 million in severance and retention expenses. Severance and retention expenses were incurred in 2021 and 2020 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 plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.

Depreciation and amortization expenses decreased primarily due to the absence of depreciation expense from Indian Point 3, after it was shut down in April 2021.

Other income decreased primarily due to lower gains on decommissioning trust fund investments, including the absence of earnings from nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Other expenses decreased primarily due to the absence of decommissioning expense from Indian Point 2 and Indian Point 3, after the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was 22.8% for the third quarter 2021. The difference in the effective income tax rate for the third quarter 2021 versus the federal statutory rate of 21% was primarily due to state income taxes, partially 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 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.

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Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020 showing how much the line items increased or (decreased) in comparison to the prior period:

Utility
Entergy
Wholesale
Commodities

Parent &
Other (a)

Entergy
(In Thousands)
2020 Net Income (Loss) Attributable to Entergy Corporation$1,216,235 $3,882 ($219,751)$1,000,366 
Operating revenues1,464,365 (187,479)20 1,276,906 
Fuel, fuel-related expenses, and gas purchased for resale693,410 11,533 (3)704,940 
Purchased power241,409 8,527 3 249,939 
Other regulatory charges (credits)107,770 — — 107,770 
Other operation and maintenance150,458 (151,789)148 (1,183)
Asset write-offs, impairments, and related charges— 328,894 — 328,894 
Taxes other than income taxes24,177 (29,821)240 (5,404)
Depreciation and amortization98,045 (45,123)(170)52,752 
Other income (deductions)44,706 (12,983)10,173 41,896 
Interest expense31,701 (6,039)5,557 31,219 
Other expenses(682)(47,113)— (47,795)
Income taxes126,183 (53,548)(34,193)38,442 
2021 Net Income (Loss) Attributable to Entergy Corporation$1,252,835 ($212,101)($181,140)$859,594 

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

Results of operations for the nine months ended September 30, 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

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Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:

Amount
(In Millions)
2020 operating revenues$6,997 
Fuel, rider, and other revenues that do not significantly affect net income1,086 
Retail electric price310 
Volume/weather84 
Return of unprotected excess accumulated deferred income taxes to customers(16)
2021 operating revenues$8,461 

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 retail electric price variance is primarily due to:

•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of May 2021;
•increases in Entergy Louisiana’s overall formula rate plan revenues, including an interim increase effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station, an increase in the transmission recovery mechanism effective September 2020, an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center, and an increase in formula rate plan revenues implemented with the first billing cycle of September 2021;
•increases in Entergy Mississippi’s formula rate plan rates effective with the first billing cycles of April 2020, April 2021, and July 2021;
•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020; and
•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021, each at Entergy Texas.

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

The volume/weather variance is primarily due to an increase of 2,547 GWh, or 3%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in industrial usage, partially offset by a decrease in weather-adjusted residential usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries, and an increase in demand from cogeneration customers, partially offset by decreased demand from existing customers in the chemicals and petroleum refining industries as a result of temporary plant shutdowns and
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operational issues. The decrease in weather-adjusted residential usage was primarily due to the effects of Hurricane Ida in the third quarter 2021 and due to the impact that the COVID-19 pandemic had on prior year usage, partially offset by the effects of Hurricane Laura in the third quarter 2020. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the impacts from the storms. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the COVID-19 pandemic.

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 the second quarter 2018. In the nine months ended September 30, 2021, $71 million was returned to customers through reductions in operating revenues as compared to $55 million in the nine months ended September 30, 2020. 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 in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

Billed electric energy sales for Utility for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential28,178 27,519 2 
Commercial20,299 20,106 1 
Industrial37,335 35,655 5 
Governmental1,841 1,826 1 
Total retail87,653 85,106 3 
Sales for resale13,365 11,109 20 
Total101,018 96,215 5 

See Note 13 to the financial statements herein for additional discussion of operating revenues.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $746 million for the nine months ended September 30, 2020 to $559 million for the nine months ended September 30, 2021 primarily due to the shutdown of Indian Point 2 in April 2020 and the shutdown of Indian Point 3 in April 2021.

Following are key performance measures for Entergy Wholesale Commodities for the nine months ended September 30, 2021 and 2020:

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20212020
Owned capacity (MW) (a) 1,2052,246
GWh billed9,26516,047
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor97%94%
GWh billed8,04614,782
Average energy price ($/MWh)$54.65$41.61
Average capacity price ($/kW-month)$0.26$2.06
Refueling outage days:
Palisades—32

(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,787 million for the nine months ended September 30, 2020 to $1,937 million for the nine months ended September 30, 2021 primarily due to:

•an increase of $33 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020, higher contract costs, higher materials and supplies costs, and higher expenses associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020; the New Orleans Power Station, which began commercial operation in May 2020; the Washington Parish Energy Center, purchased in November 2020; and the Montgomery County Power Station, which began commercial operation in January 2021;
•an increase of $29 million in distribution operations expenses primarily due to higher contractor costs, higher reliability costs, and higher vegetation maintenance costs;
•an increase of $27 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, and a higher scope of work performed in 2021 as compared to 2020;
•an increase of $25 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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;
•lower nuclear insurance refunds of $13 million;
•an increase of $12 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements in the Form 10-K for further information on the recovery of these costs;
•an increase of $10 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives; and
•several individually insignificant items.

The increase was partially offset by a gain of $15 million, recorded in 2021, on the sale of a pipeline and a decrease of $14 million in meter reading expenses as a result of the deployment of advanced metering systems.

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Taxes other than income taxes increased primarily due to increases in ad valorem taxes resulting from higher assessments and increases in franchise taxes.

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

Other regulatory charges (credits) - net includes:

•regulatory credits of $36 million, recorded in 2020 at Entergy Arkansas, to reflect the 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;
•the reversal in 2021 of the remaining $39 million regulatory liability for Entergy Arkansas’s 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements herein and in the Form 10-K for discussion of Entergy Arkansas’s 2020 formula rate plan filing;
•$29 million recorded in the first quarter 2020, at Entergy Louisiana, due to a settlement with the IRS related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 3 to the financial statements in the Form 10-K for further discussion of the settlement and savings obligation;
•regulatory credits of $20 million, recorded in the second quarter 2021 at Entergy Mississippi, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing; and
•regulatory credits of $10 million, recorded in the first quarter 2020 at Entergy New Orleans, to reflect compliance with terms of the 2018 combined rate case resolution approved by the City Council in February 2020.

Entergy records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and trust earnings plus asset retirement obligation related costs collected in revenue. Entergy Arkansas recorded regulatory charges in the third quarter 2021 as a result of portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds.

Other income increased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of certain of the decommissioning trust funds in 2021, partially offset by a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.

Interest expense increased primarily due to:

•the issuance by Entergy Louisiana of $350 million of 2.90% Series mortgage bonds in March 2020;
•the issuances by Entergy Louisiana of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;
•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;
•the issuance by Entergy Mississippi of $170 million of 3.50% Series mortgage bonds in May 2020 and an additional $200 million in a reopening of the same series in March 2021; and
•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.

The increase was partially offset by:

•the repayments by Entergy Louisiana of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020; and
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•the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $385 million for the nine months ended September 30, 2020 to $233 million for the nine months ended September 30, 2021 primarily due to:

•a decrease of $112 million resulting from the absence of expenses from Indian Point 2, after it was shut down in April 2020, and Indian Point 3, after it was shut down in April 2021; and
•a decrease of $43 million in severance and retention expenses. Severance and retention expenses were incurred in 2021 and 2020 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 Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.

Asset write-offs, impairments, and related charges for the nine months ended September 30, 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center. 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.

Taxes other than income taxes decreased primarily due to lower payroll taxes and lower ad valorem taxes.

Depreciation and amortization expenses decreased primarily due to:

•the absence of depreciation expense from Indian Point 2, after it was shut down in April 2020, and from Indian Point 3, after it was shut down in April 2021; and
•the effect of recording in 2021 a final judgment to resolve claims in the Palisades damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included $9 million of spent nuclear fuel storage costs previously recorded as depreciation expense. See Note 1 to the financial statements herein for discussion of the spent nuclear fuel litigation.

Other income decreased primarily due to lower gains on decommissioning trust fund investments including the absence of earnings from nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021. The decrease was partially offset by lower non-service pension costs. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center. See 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 benefits costs.

Other expenses decreased primarily due to the absence of decommissioning expense from Indian Point 2 and Indian Point 3, after the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was 19.1% for the nine months ended September 30, 2021. The difference in the effective income tax rate for the nine months ended September 30, 2021 versus the federal statutory rate of 21%
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was primarily due to the amortization of excess accumulated deferred income taxes, a reduction of a valuation allowance, book and tax differences related to the allowance for equity funds used during construction, 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. See Note 10 to the financial statements herein for discussion of the valuation allowance reduction.

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 3 to the financial statements in the Form 10-K 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.

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 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 to a Holtec subsidiary for decommissioning the plants.

In November 2019, Entergy and Holtec submitted a license transfer application to the NRC. The NRC issued an order approving the application in November 2020, subject to the NRC’s authority to condition, revise, or rescind the approval order based on the resolution of four pending hearing requests. In January 2021 the NRC issued an order denying all four hearing requests challenging the license transfer application. In January 2021, New York State filed a petition for review with the D.C. Circuit asking the court to vacate the NRC’s January 2021 order denying the State’s hearing request, as well as the NRC’s November 2020 order approving the license transfers. In March 2021 additional parties also filed petitions for review with the D.C. Circuit seeking review of the same NRC orders. In March 2021 the court consolidated all of the appeals into the same proceeding. Pursuant to an April 2021 settlement among Entergy, Holtec, New York State, and several other parties, discussed below, all petitioners to the D.C. Circuit proceeding withdrew their pending appeals, and the court terminated the consolidated proceeding in June 2021.

In November 2019, Entergy and Holtec also submitted a petition to the New York State Public Service Commission (NYPSC) seeking an order from the NYPSC disclaiming jurisdiction or abstaining from review of the transaction or, alternatively, approving the transaction. Closing was also conditioned on obtaining from the New York State Department of Environmental Conservation an agreement related to Holtec’s decommissioning plan as being consistent with applicable standards. In April 2021, Entergy and Holtec filed a joint settlement proposal with the NYPSC that resolved all issues among all parties, including financial assurance, site restoration, financial reporting, continued funding for state and local emergency management and response activities, a memorandum of understanding with local taxing jurisdictions, and the dismissal of the federal appeals described in the preceding paragraph. In May 2021 the NYPSC approved the joint settlement proposal and the transaction.

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Indian Point 2 permanently ceased operations on April 30, 2020 and Indian Point 3 permanently ceased operations on April 30, 2021. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. See Note 14 to the financial statements for discussion of the closing of the Indian Point transaction.

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) to a Holtec subsidiary. The sale will include the transfer of the nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning.

In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC has indicated that it expects to complete its review of the application by January 2022. In February 2021 several parties filed with the NRC petitions to intervene and requests for hearing challenging the license transfer application. In March 2021, Entergy and Holtec filed answers opposing the petitions to intervene and hearing requests, and the petitioners filed replies. In March 2021 an additional party also filed a petition to intervene and request for hearing. Entergy and Holtec filed an answer to the March 2021 petition in April 2021.

Subject to the conditions discussed in the Form 10-K, the transaction is expected to close by the end of 2022. Entergy intends to shut down Palisades permanently no later than May 31, 2022. As of September 30, 2021, Entergy’s adjusted net investment in Palisades was ($25) 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.

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 $10 million in 2021, of which $9 million has been incurred as of September 30, 2021, and a total of approximately $5 million in 2022. In addition, Entergy Wholesale Commodities incurred impairment charges primarily related to expenditures for capital assets of $5 million for the nine months ended September 30, 2021. 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.

Liquidity and Capital Resources

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

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Capital Structure 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, 2021 is primarily due to the net issuance of debt in 2021.
September 30,
2021		December 31,
2020
Debt to capital69.1 %68.3 %
Effect of excluding securitization bonds(0.1 %)(0.2 %)
Debt to capital, excluding securitization bonds (a)69.0 %68.1 %
Effect of subtracting cash(0.9 %)(1.7 %)
Net debt to net capital, excluding securitization bonds (a)68.1 %66.4 %

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

As of September 30, 2021, 23.3% of the debt outstanding is at the parent company, Entergy Corporation, 76.2% is at the Utility, and 0.5% is at Entergy Wholesale Commodities. 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 June 2026.  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, 2021 was 1.60% 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, 2021:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$325$6$3,169
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
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billion. As of September 30, 2021, Entergy Corporation had approximately $1,006 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2021 was 0.30%.

Entergy Mississippi had a total of $33 million in storm reserve escrow accounts at September 30, 2021.

Equity Issuances and Equity Distribution Program

Entergy Corporation currently expects to issue approximately $1.5 billion of equity from 2021 through 2024. Entergy is considering various methods, including, among others, at the market distributions, block trades, and preferred equity issuances. In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. See Note 3 to the financial statements herein for discussion of the forward sales agreements and common stock issuances and sales under the equity distribution program.

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 2021 through 2023. Following are updates to that discussion.

Preliminary Capital Investment Plan Estimate for 2022-2024

Entergy is developing its capital investment plan for 2022 through 2024 and currently anticipates that the Utility will make approximately $11.7 billion in capital investments during that period, excluding capital spending as a result of Hurricane Ida, and that Entergy Wholesale Commodities will make approximately $5 million in capital investments during that period. The preliminary Utility estimate includes generation projects to modernize, decarbonize, and diversify Entergy’s portfolio, such as the Sunflower Solar Facility, West Memphis Solar Facility, Walnut Bend Solar Facility, and Orange County Advanced Power Station; investments in Entergy’s nuclear fleet; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; and other investments. 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.

Searcy Solar Facility

As discussed in the Form 10-K, in April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. Subject to the terms of the tax equity partnership, Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occur by the end of 2021.

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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 primarily requested cost recovery through the formula rate plan rider. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2022.

West Memphis Solar Facility

In January 2021, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 180 MW West Memphis Solar Facility is in the public interest. In October 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the West Memphis Solar Facility and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2023.

Sunflower Solar Facility

As discussed in the Form 10-K, in November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW 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 project is being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. 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 to recover the non-fuel related costs of additional owned capacity owned by Entergy Mississippi, including the annual ownership costs of the Sunflower Solar Facility. Recovery through the interim capacity rate adjustment requires MPSC approval for each new resource. 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 second quarter 2022.

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. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. In July 2021 the presiding ALJs issued a proposal for decision recommending that the PUCT deny the certification requested in the application. In October 2021 the PUCT issued an order adopting the ALJs’ proposal for decision and denying Entergy Texas’s application. Entergy Texas is reviewing the order and evaluating its options.

Orange County Advanced Power Station

In September 2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to construct, own, and operate the Orange County Advanced Power Station, a new 1,215 MW combined-cycle combustion turbine facility to be located in Bridge City, Texas at an expected
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total cost of $1.19 billion inclusive of the estimated costs of the generation facilities, transmission upgrades, contingency, an allowance for funds used during construction, and necessary regulatory expenses, among others. The project includes combustion turbine technology with dual fuel capability, able to co-fire up to 30% hydrogen by volume upon commercial operation and upgradable to support 100% hydrogen operations in the future. Subject to receipt of required regulatory approvals and other conditions, the facility is expected to be in-service by May 2026.

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 2021 meeting, the Board declared a dividend of $1.01 per share, an increase from the previous $0.95 quarterly dividend per share that Entergy has paid since the third quarter 2020.

Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Millions)
Cash and cash equivalents at beginning of period$1,759 $426 
Cash flow provided by (used in):  
Operating activities2,011 2,370 
Investing activities(3,862)(3,256)
Financing activities1,092 1,700 
Net increase (decrease) in cash and cash equivalents(759)814 
Cash and cash equivalents at end of period$1,000 $1,240 

Operating Activities

Net cash flow provided by operating activities decreased $359 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to the following activity:

•increased fuel costs, including those related to Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;
•an increase of approximately $178 million in storm spending. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of storm restoration efforts;
•an increase of $158 million in pension contributions in 2021 as compared to the same period 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;
•lower Entergy Wholesale Commodities revenues in 2021;
•an increase of $104 million in severance and retention payments in 2021 as compared to prior period. See Note 7 to the financial statements herein for a discussion of the severance and retention payments related to Entergy Wholesale Commodities. See “Entergy Wholesale Commodities Exit from the Merchant
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Power Business” above for a discussion of management’s strategy to exit the Entergy Wholesale Commodities merchant power business;
•income tax payments of $29 million in 2021 compared to income tax refunds of $2 million in 2020. Entergy had net income tax payments in 2021 as a result of amended Mississippi state tax returns filed and other state income taxes paid, offset by federal income tax refunds received associated with the completion of the 2014-2015 IRS audit. Entergy had income tax refunds in 2020 as a result of an overpayment on a prior year state income tax return;
•a decrease of $20 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
•a decrease of $18 million of nuclear insurance refunds.

The decrease was partially offset by:

•the timing of collections of receivables from customers;
•the effect of more favorable weather on billed Utility sales in 2021; and
•a decrease in spending of $25 million on nuclear refueling outages in 2021 as compared to prior period.

Investing Activities

Net cash flow used in investing activities increased $606 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•an increase of $874 million in distribution construction expenditures primarily due to storm spending in 2021 and increased spending on the reliability and infrastructure of the distribution system, partially offset by lower spending in 2021 on advanced metering infrastructure; and
•an increase of $265 million in transmission construction expenditures primarily due to storm spending in 2021, partially offset by a lower scope of work on non-storm projects performed in 2021 as compared to 2020.

See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of storm restoration efforts. The increase was partially offset by:

•a decrease of $258 million in non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station, Lake Charles Power Station, New Orleans Power Station, and New Orleans Solar Station projects;
•a decrease of $76 million in nuclear construction expenditures primarily due to decreased spending on various nuclear projects in 2021;
•a decrease of $75 million in decommissioning trust fund investment activity;
•a decrease of $50 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;
•a decrease of $45 million in information technology expenditures primarily due to decreased spending on various technology projects in 2021, including advanced metering infrastructure; and
•an increase of $45 million in net receipts from storm reserve escrow accounts.

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Management's Financial Discussion and Analysis
Financing Activities

Net cash flow provided by financing activities decreased $608 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•long-term debt activity providing approximately $2,222 million of cash in 2021 compared to providing approximately $2,784 million of cash in 2020;
•an increase of $73 million in net repayments of commercial paper in 2021 compared to 2020; and
•a decrease of $36 million in treasury stock issuances in 2021 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2020 to satisfy stock option exercises.

The decrease was partially offset by:

•an increase of $50 million primarily due to higher prepaid deposits related to contributions-in-aid-of-construction generation interconnection agreements in 2021 as compared to 2020; and
•net sales proceeds of $27 million from the issuance of common stock in 2021 under the at the market equity distribution program. See Note 3 to the financial statements herein for discussion of the equity distribution program.

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.

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.  See “Entergy Wholesale Commodities Exit from the Merchant Power Business” above and 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.  As of September 30, 2021, Palisades is the only remaining plant in the Entergy Wholesale Commodities merchant nuclear fleet. Almost all of the Palisades output is sold under a power purchase agreement that is scheduled to expire in 2022. Planned generation currently under contract from the Palisades plant is 99% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 1.7 TWh.
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Management's Financial Discussion and Analysis


Entergy Wholesale Commodities Portfolio

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, 2021, based on power prices at that time, Entergy had liquidity exposure of $33 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $7 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, 2021, 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, 2021, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by an insignificant amount for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of September 30, 2021, substantially all of the credit exposure associated with the planned energy output under contract for the Palisades plant 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. Following are updates to the discussion in the Form 10-K.

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. Nuclear generating plants owned and operated by Entergy’s Utility and Entergy Wholesale Commodities businesses are currently in Column 1, except for Grand Gulf, which is in Column 3.

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC conducted a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3 and, in October 2021, notified Entergy that all inspection objectives were met. A formal report on the inspection is expected in late 2021.

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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’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

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

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands, Except Share Data)
OPERATING REVENUES
Electric$3,159,969 $2,666,805 $8,339,764 $6,907,999 
Natural gas31,254 22,357 121,420 88,829 
Competitive businesses162,309 214,406 559,256 746,706 
TOTAL3,353,532 2,903,568 9,020,440 7,743,534 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale737,785 421,668 1,865,016 1,160,076 
Purchased power311,332 264,924 943,438 693,499 
Nuclear refueling outage expenses43,309 44,384 130,747 139,496 
Other operation and maintenance700,595 751,337 2,188,498 2,189,681 
Asset write-offs, impairments, and related charges(139)4,461 345,226 16,332 
Decommissioning60,364 95,155 245,205 284,251 
Taxes other than income taxes182,347 171,425 494,960 500,364 
Depreciation and amortization421,745 401,578 1,257,809 1,205,057 
Other regulatory charges (credits) - net68,324 (29,380)45,464 (62,306)
TOTAL2,525,662 2,125,552 7,516,363 6,126,450 
OPERATING INCOME 827,870 778,016 1,504,077 1,617,084 
OTHER INCOME
Allowance for equity funds used during construction17,180 24,915 48,629 89,238 
Interest and investment income75,112 127,857 289,757 195,826 
Miscellaneous - net(16,797)(58,914)(140,571)(129,145)
TOTAL75,495 93,858 197,815 155,919 
INTEREST EXPENSE
Interest expense216,612 207,811 642,839 630,199 
Allowance for borrowed funds used during construction(7,112)(11,080)(20,088)(38,667)
TOTAL209,500 196,731 622,751 591,532 
INCOME BEFORE INCOME TAXES
693,865 675,143 1,079,141 1,181,471 
Income taxes158,282 149,444 205,808 167,366 
CONSOLIDATED NET INCOME535,583 525,699 873,333 1,014,105 
Preferred dividend requirements of subsidiaries4,580 4,580 13,739 13,739 
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
$531,003 $521,119 $859,594 $1,000,366 
Earnings per average common share:
Basic$2.64 $2.60 $4.28 $5.00 
Diluted$2.63 $2.59 $4.26 $4.98 
Basic average number of common shares outstanding200,963,049 200,220,018 200,756,267 200,063,256 
Diluted average number of common shares outstanding202,003,329 201,115,768 201,568,508 200,957,465 
See Notes to Financial Statements.

24
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)
Net Income $535,583 $525,699 $873,333 $1,014,105 
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of $—, ($4,408), ($7,935), and ($16,945))
24 (16,558)(29,778)(63,674)
Pension and other postretirement liabilities (net of tax expense of $2,596, $4,697, $15,141, and $24,487)
8,838 17,437 53,903 88,560 
Net unrealized investment gain (loss) (net of tax expense (benefit) of ($1,259), ($1,513), ($26,867), and $18,042)
(2,162)(2,695)(46,957)31,614 
Other comprehensive income (loss)6,700 (1,816)(22,832)56,500 
Comprehensive Income 542,283 523,883 850,501 1,070,605 
Preferred dividend requirements of subsidiaries4,580 4,580 13,739 13,739 
Comprehensive Income Attributable to Entergy Corporation$537,703 $519,303 $836,762 $1,056,866 
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, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Consolidated net income $873,333 $1,014,105 
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization1,696,323 1,694,904 
Deferred income taxes, investment tax credits, and non-current taxes accrued280,193 320,726 
Asset write-offs, impairments, and related charges345,200 16,117 
Changes in working capital:
Receivables(245,082)(200,990)
Fuel inventory46,951 (608)
Accounts payable362,529 174,083 
Taxes accrued19,611 206,769 
Interest accrued29,313 10,866 
Deferred fuel costs(356,833)(48,162)
Other working capital accounts(94,791)(114,492)
Changes in provisions for estimated losses(72,577)(38,029)
Changes in other regulatory assets(631,172)(130,533)
Changes in other regulatory liabilities117,301 (38,371)
Changes in pension and other postretirement liabilities(422,028)(270,144)
Other62,712 (226,075)
Net cash flow provided by operating activities2,010,983 2,370,166 
INVESTING ACTIVITIES
Construction/capital expenditures(3,925,632)(3,175,559)
Allowance for equity funds used during construction48,629 89,238 
Nuclear fuel purchases(127,606)(177,385)
Payment for purchase of plant or assets(36,534)(24,633)
Net proceeds from sale of assets 17,421 — 
Changes in securitization account13,862 791 
Payments to storm reserve escrow account(23)(2,244)
Receipts from storm reserve escrow account83,105 40,647 
Increase (decrease) in other investments4,239 (9,821)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs49,236 67,252 
Proceeds from nuclear decommissioning trust fund sales4,475,142 1,597,492 
Investment in nuclear decommissioning trust funds(4,463,814)(1,661,660)
Net cash flow used in investing activities(3,861,975)(3,255,882)
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, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt6,269,152 8,170,607 
Treasury stock5,613 41,784 
Common stock26,817 — 
Retirement of long-term debt(4,046,791)(5,386,227)
Changes in credit borrowings and commercial paper - net(621,168)(548,522)
Other44,176 (5,941)
Dividends paid:
Common stock(572,131)(558,121)
Preferred stock(13,739)(13,922)
Net cash flow provided by financing activities1,091,929 1,699,658 
Net increase (decrease) in cash and cash equivalents(759,063)813,942 
Cash and cash equivalents at beginning of period1,759,099 425,722 
Cash and cash equivalents at end of period$1,000,036 $1,239,664 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$590,581 $599,683 
Income taxes$29,454 ($2,484)
See Notes to Financial Statements.
27
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$44,215 $128,851 
Temporary cash investments955,821 1,630,248 
Total cash and cash equivalents1,000,036 1,759,099 
Accounts receivable:
Customer981,996 833,478 
Allowance for doubtful accounts(96,087)(117,794)
Other159,252 135,208 
Accrued unbilled revenues485,648 434,835 
Total accounts receivable1,530,809 1,285,727 
Deferred fuel costs209,853 4,380 
Fuel inventory - at average cost125,983 172,934 
Materials and supplies - at average cost1,032,260 962,185 
Deferred nuclear refueling outage costs140,642 179,150 
Prepayments and other193,084 196,424 
TOTAL4,232,667 4,559,899 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds5,235,496 7,253,215 
Non-utility property - at cost (less accumulated depreciation)352,706 343,328 
Other123,720 214,222 
TOTAL5,711,922 7,810,765 
PROPERTY, PLANT, AND EQUIPMENT
Electric61,608,960 59,696,443 
Natural gas642,708 610,768 
Construction work in progress2,912,379 2,012,030 
Nuclear fuel534,169 601,281 
TOTAL PROPERTY, PLANT, AND EQUIPMENT65,698,216 62,920,522 
Less - accumulated depreciation and amortization24,509,241 24,067,745 
PROPERTY, PLANT, AND EQUIPMENT - NET41,188,975 38,852,777 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $63,783 as of September 30, 2021 and $119,238 as of December 31, 2020)
6,707,721 6,076,549 
Deferred fuel costs240,820 240,422 
Goodwill377,172 377,172 
Accumulated deferred income taxes58,069 76,289 
Other326,153 245,339 
TOTAL7,709,935 7,015,771 
TOTAL ASSETS$58,843,499 $58,239,212 
See Notes to Financial Statements.
28
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$770,329 $1,164,015 
Notes payable and commercial paper1,006,321 1,627,489 
Accounts payable3,452,217 2,739,437 
Customer deposits390,423 401,512 
Taxes accrued460,622 441,011 
Interest accrued231,104 201,791 
Deferred fuel costs2,150 153,113 
Pension and other postretirement liabilities67,361 61,815 
Current portion of unprotected excess accumulated deferred income taxes69,768 63,683 
Other194,605 206,640 
TOTAL6,644,900 7,060,506 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued4,555,119 4,361,772 
Accumulated deferred investment tax credits213,768 212,494 
Regulatory liability for income taxes-net1,396,385 1,521,757 
Other regulatory liabilities2,560,439 2,323,851 
Decommissioning and asset retirement cost liabilities4,696,558 6,469,452 
Accumulated provisions170,258 242,835 
Pension and other postretirement liabilities2,425,439 2,853,013 
Long-term debt (includes securitization bonds of $89,665 as of September 30, 2021 and $174,635 as of December 31, 2020)
23,846,675 21,205,761 
Other827,024 807,219 
TOTAL40,691,665 39,998,154 
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund219,410 219,410 
EQUITY
Preferred stock, no par value, authorized 1,000,000 shares in 2021 and 0 shares in 2020; issued shares in 2021 and 2020 - none
— — 
Common stock, $.01 par value, authorized 499,000,000 shares in 2021 and 500,000,000 shares in 2020; issued 270,300,648 shares in 2021 and 270,035,180 shares in 2020
2,703 2,700 
Paid-in capital6,577,852 6,549,923 
Retained earnings10,184,645 9,897,182 
Accumulated other comprehensive loss(472,039)(449,207)
Less - treasury stock, at cost (69,325,211 shares in 2021 and 69,790,346 shares in 2020)
5,040,637 5,074,456 
Total common shareholders' equity11,252,524 10,926,142 
Subsidiaries' preferred stock without sinking fund35,000 35,000 
TOTAL11,287,524 10,961,142 
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY$58,843,499 $58,239,212 
See Notes to Financial Statements.
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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2021
(Unaudited)
Common Shareholders’ Equity
Subsidiaries’ Preferred StockCommon
Stock		Treasury
Stock		Paid-in
Capital		Retained EarningsAccumulated Other Comprehensive LossTotal
(In Thousands)
Balance at December 31, 2020$35,000 $2,700 ($5,074,456)$6,549,923 $9,897,182 ($449,207)$10,961,142 
Consolidated net income (a)4,580 — — — 334,565 — 339,145 
Other comprehensive loss— — — — — (51,300)(51,300)
Common stock issuances related to stock plans
— — 28,235 (29,871)— — (1,636)
Common stock dividends declared— — — — (190,595)— (190,595)
Preferred dividend requirements of subsidiaries (a)
(4,580)— — — — — (4,580)
Balance at March 31, 2021$35,000 $2,700 ($5,046,221)$6,520,052 $10,041,152 ($500,507)$11,052,176 
Consolidated net income (loss) (a)4,580 — — — (5,974)— (1,394)
Other comprehensive income— — — — — 21,768 21,768 
Common stock issuances and sales under the at the market equity distribution program — 3 — 28,213 — — 28,216 
Common stock issuance costs— — — (1,399)— — (1,399)
Common stock issuances related to stock plans
— — 3,979 14,810 — — 18,789 
Common stock dividends declared— — — — (190,629)— (190,629)
Preferred dividend requirements of subsidiaries (a)
(4,580)— — — — — (4,580)
Balance at June 30, 2021$35,000 $2,703 ($5,042,242)$6,561,676 $9,844,549 ($478,739)$10,922,947 
Consolidated net income (a)4,580 — — — 531,003 — 535,583 
Other comprehensive income— — — — — 6,700 6,700 
Common stock issuances related to stock plans— — 1,605 16,176 — — 17,781 
Common stock dividends declared— — — — (190,907)— (190,907)
Preferred dividend requirements of subsidiaries (a)(4,580)— — — — — (4,580)
Balance at September 30, 2021$35,000 $2,703 ($5,040,637)$6,577,852 $10,184,645 ($472,039)$11,287,524 
See Notes to Financial Statements.
(a) Consolidated net income (loss) and preferred dividend requirements of subsidiaries for first quarter 2021, second quarter 2021, and third quarter 2021 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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ENTERGY CORPORATION AND SUBSIDIARIES
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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ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS
(Unaudited)

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. In October 2021 the APSC approved Entergy Arkansas’s request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding.

In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana
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Notes to Financial Statements
received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. The judgment has been submitted to the U.S. Treasury for payment.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

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

Employment and Labor-related Proceedings

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

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

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

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.

Hurricane Ida

In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida are currently estimated to be in the range of $2.1 billion to $2.5 billion. Most of the storm costs were incurred by Entergy Louisiana and Entergy New Orleans. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.
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Notes to Financial Statements

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 $850 million, including $800 million at Entergy Louisiana and $45 million at Entergy New Orleans, and construction work in progress of approximately $1.3 billion, including $1.2 billion at Entergy Louisiana and $75 million at Entergy New Orleans. 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.

Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of approximately $1 billion of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

As discussed in the Form 10-K, in January 2014, Entergy Arkansas filed a motion with the APSC relating to its energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regarding various claims associated with the ANO stator incident. In February 2014 the APSC approved Entergy Arkansas’s request to retain that amount in its deferred fuel balance. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. See the “ANO Damage, Outage, and NRC Reviews” section in Note 8 to the financial statements in the Form 10-K for further discussion of the ANO stator incident.

In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.
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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. In September 2021 the LPSC submitted its audit report and found that all costs recovered through the fuel adjustment clause were reasonable and eligible for recovery through the fuel adjustment clause. The report did contain prospective recommendations on internal informational reporting.

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. Discovery is ongoing, and no audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-
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Entergy Corporation and Subsidiaries
Notes to Financial Statements
year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.

2021 Formula Rate Plan Filing

In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. 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 exceeded the constraint, the resulting increase is limited to $72.4 million. In October 2021, Entergy Arkansas filed with the APSC a settlement agreement reached with other parties resolving all issues in the proceeding. As a result of the settlement agreement, the total proposed revenue change is $82.2 million, including a $62.8 million increase for the projected 2022 year and a $19.4 million netting adjustment. Because Entergy Arkansas’s revenue requirement exceeded the constraint, the resulting increase is limited to $72.1 million. Also in October 2021 the APSC issued an order canceling the evidentiary hearing, accepting all filed testimony and exhibits into the record, and excusing all witnesses. The APSC will rule on the settlement agreement at a later date.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. In August 2021 the APSC general staff filed a report recommending that utilities with a formula rate plan discontinue capturing any additional direct costs and savings as a regulatory asset and seek cost recovery through the formula rate plan. The APSC general staff further recommended that uncollectible amounts should be determined as of the end of its write-off period, approximately December 2021, and recovered in the next formula rate plan filing over one year. In November 2021 the APSC found the APSC general staff’s recommendation to be premature and asked utilities to report on the continued need for a regulatory asset. As of September 30, 2021, Entergy Arkansas had a regulatory asset of $24.5 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 June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations, and filed a supplemental formula rate plan evaluation report in August 2018. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2017 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objections/reservations pertaining to Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Cuts and Jobs Act and the treatment of accumulated deferred income taxes related to reductions of rate base, specifically how the accumulated deferred income taxes associated with uncertain tax positions have been accounted for, and test year expenses billed from Entergy Services to Entergy Louisiana. The LPSC staff further reserved its rights for future proceedings and to dispute future proposed adjustments to the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations.

As also 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). In February 2021 the LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. The LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between the LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.

2018 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2018 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objection/reservation pertaining to test year expenses billed from Entergy Services to Entergy Louisiana and outstanding issues from the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations.

2019 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its formula rate plan evaluation report for its 2019 calendar year operations. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2019 test year formula rate plan filing. In its letter, the LPSC staff disputes Entergy Louisiana’s exclusion of approximately $251 thousand of interest income allocated from Entergy Operations and Entergy Services to Entergy Louisiana to the extent that there are other adjustments that would move Entergy Louisiana out of the formula rate plan deadband. The LPSC staff reserved the right to further contest the issue in future proceedings. The LPSC staff further reserved outstanding issues from the 2017 and 2018 formula rate plan evaluation reports and withdrew all other remaining objections/reservations.


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Notes to Financial Statements
Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

2020 Formula Rate Plan Filing

In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes became effective for bills rendered during the first billing cycle of September 2021. Discovery commenced in the proceeding. In August 2021, Entergy Louisiana submitted an update to its evaluation report to account for various changes. Relative to the June 2021 filing, the total formula rate plan revenue increased by $14.2 million to an updated total of $64.9 million. Legacy Entergy Louisiana formula rate plan revenues will increase by $32.8 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $32.1 million. The results of the 2020 test year evaluation report bandwidth calculation were unchanged as there was no change in the earned return on common equity of 8.45%. In September 2021 the LPSC staff filed a letter with a general statement of objections/reservations because it had not completed its review, and indicated it would update the letter once its review was complete. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.

COVID-19 Orders

As discussed in the Form 10-K, 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. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana had a regulatory asset of $59.2 million for costs associated with the COVID-19 pandemic.

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Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of September 30, 2021, Entergy Mississippi had a regulatory asset of $18.2 million for costs associated with the COVID-19 pandemic.


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Filings with the City Council (Entergy New Orleans)

2021 Formula Rate Plan Filing

In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans sought approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula resulted in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also sought to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing was subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. In October 2021 the City Council’s advisors filed a 75-day report recommending a reduction of $10 million for electric revenues and a reduction of $4.5 million for gas revenues, along with one-time credits funded by certain electric regulatory liabilities currently held by Entergy New Orleans for customers. Other parties filed reports arguing that no rate should be implemented until the completion of a management audit of Entergy New Orleans. On October 26, 2021, Entergy New Orleans provided notice to the City Council that it intends to implement rates effective with the first billing cycle of November 2021, with such rates reflecting an amount agreed-upon by Entergy New Orleans including adjustments filed in the City Council’s 75-day report, per the approved process for formula rate plan implementation. The total formula rate plan increase implemented will be $49.5 million, with an increase of $34.9 million in electric revenues and $14.6 million in gas revenues. Also, credits of $17.4 million funded by certain regulatory liabilities currently held by Entergy New Orleans for customers will be issued over a five-month period from November 2021 through March 2022. Resulting rates went into effect with the first billing cycle of November 2021 pursuant to the formula rate plan tariff.

COVID-19 Orders

As discussed in the Form 10-K, 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 and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program was effective from July 1, 2020 through December 31, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. Credits of $4.3 million were applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of September 30, 2021, Entergy New Orleans had a regulatory asset of $12.7 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, 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 then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February
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2021 the ALJ with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement.

In August 2021, 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 $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. A procedural schedule was established with a hearing scheduled in December 2021.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, 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 then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the ALJ granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement.

In October 2021, 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 $66.1 million annually, or $15.1 million in incremental annual revenues beyond Energy Texas’s currently effective TCRF rider based on its capital invested in transmission between September 1, 2020 and July 31, 2021 and changes in approved transmission charges.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding and in May 2021 the ALJ issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the ALJ with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the ALJ. In October 2021, Entergy Texas filed on behalf of the parties an unopposed settlement agreement that would adjust its generation cost recovery rider to recover its investment in the Montgomery County Power Station through January 1, 2021, with Entergy Texas able to seek recovery of the remainder of its investment in its next base rate case. Also in October 2021 the ALJ granted a motion to admit evidence and remand the proceeding to the PUCT.
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In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings for further processing. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. 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. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of September 30, 2021, Entergy Texas had a regulatory asset of $12.8 million for costs associated with the COVID-19 pandemic.

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. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, 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. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that
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the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $60 million, which includes interest through September 30, 2021, and the estimated resulting annual rate reduction would be approximately $45 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has a provision recorded of $37 million, including interest, as of September 30, 2021.

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. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

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. 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 that 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, 2021, is approximately $422 million, plus interest, which is approximately $123 million through September 30, 2021. 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, 2021.

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. 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
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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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, 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 the 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.”

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first 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. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of
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Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay has expired.

In August 2021 the FERC issued an order addressing System Energy’s and the complainants’ rehearing requests. The FERC dismissed part of the complaint seeking an equity reopener, maintained the abeyance for issues related to the proceeding addressing the sale-leaseback renewal and uncertain tax positions, lifted the abeyance for issues unrelated to that proceeding, and clarified the scope of the hearing. A procedural schedule was established, with the hearing scheduled for June 2022 and the ALJ’s initial decision scheduled for November 2022. Discovery is ongoing.

Grand Gulf Prudence Complaint

The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants and System Energy during the period from March through July 2021.

Storm Cost Filings with Retail Regulators

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

In August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.

In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint
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motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana withdrew $257 million from its funded storm reserves.

In February 2021, two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs, and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana recovered the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs, as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. In September 2021, Entergy Louisiana supplemented the application with a request to establish and securitize a $1 billion restricted storm escrow account for Hurricane Ida related restoration costs, subject to a subsequent prudence review. In total, Entergy Louisiana requested authorization for the issuance of system restoration bonds in one or more series in an aggregate principal amount of $3.18 billion, which includes the costs of re-establishing and funding a storm damage escrow account, carrying costs and unamortized debt costs on interim financing, and issuance costs. In October 2021 an updated procedural schedule was established with a hearing in March 2022.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. In May 2021, Entergy New Orleans filed an application with the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs, were reasonable and necessary to enable Entergy New Orleans to restore electric service to its customers and Entergy New Orleans’s electric utility infrastructure. Additionally, Entergy New Orleans plans to make a separate filing at an appropriate time to the City Council requesting replenishment of its storm reserves.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

In August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and
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transmission infrastructure, and the loss of sales during the power outages. In April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing included only a portion of the Winter Storm Uri costs. The filing also included the projected balance of $13 million of a regulatory asset containing previously approved system restoration costs related to Hurricane Harvey. In September 2021 the parties filed an unopposed settlement agreement pursuant to which, if approved, Entergy Texas would remove from the amount it proposed to securitize approximately $4.3 million that would instead be charged to its storm reserve, $5 million related to no particular issue, of which Entergy Texas would be permitted to seek recovery in a future proceeding, and $300 thousand related to attestation costs.

In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of the system restoration costs that are the subject of the April 2021 application. A procedural schedule was established with a deadline to file a settlement agreement or status update by November 11, 2021 and a supplemental procedural schedule if no settlement is filed within seven days of a PUCT final order in Entergy Texas’s system restoration cost proceeding.


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,
20212020
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings per share
Net income attributable to Entergy Corporation$531.0 201.0 $2.64 $521.1 200.2 $2.60 
Average dilutive effect of:
Stock options0.4 — 0.4 — 
Other equity plans0.6 (0.01)0.5 (0.01)
Diluted earnings per share$531.0 202.0 $2.63 $521.1 201.1 $2.59 

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.0 million for the three months ended September 30, 2021 and approximately 0.5 million for the three months ended September 30, 2020.

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:
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For the Nine Months Ended September 30,
20212020
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings per share
Net income attributable to Entergy Corporation$859.6 200.8 $4.28 $1,000.4 200.1 $5.00 
Average dilutive effect of:
Stock options0.4 (0.01)0.4 (0.01)
Other equity plans0.4 (0.01)0.5 (0.01)
Diluted earnings per share$859.6 201.6 $4.26 $1,000.4 201.0 $4.98 

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.0 million for the nine months ended September 30, 2021 and approximately 0.5 million for the nine months ended September 30, 2020.

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 $0.95 for the three months ended September 30, 2021 and $0.93 for the three months ended September 30, 2020. Dividends declared per common share were $2.85 for the nine months ended September 30, 2021 and $2.79 for the nine months ended September 30, 2020.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion.

For the three months ended September 30, 2021, there were no shares of common stock issued under the at the market equity distribution program. During the nine months ended September 30, 2021, Entergy Corporation issued 265,468 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $26.8 million, which includes the gross sales price of $28.2 million received by Entergy Corporation less $1.1 million of general issuance costs and $0.3 million of aggregate compensation to the agents with respect to such sales.

In June 2021, Entergy entered into a forward sale agreement for 416,853 shares of common stock. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $106.87 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, which have not been deducted from the gross sales price. Entergy did not receive any proceeds from such sales of borrowed shares.
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In August and October 2021, Entergy entered into forward sale agreements for 1,692,555 and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. In each case, the forward sale agreement requires Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 1,692,555 and 250,743 shares, respectively, of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the respective forward sale agreement (initially approximately $111.16 and $100.35 per share, respectively) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the respective forward sale agreement. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,692,555 and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $190.1 million and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $1.9 million and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares.

Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. For the three and nine months ended September 30, 2021, shares under the forward sale agreement were not included in the calculation of diluted common shares outstanding because their effect would have been antidilutive.

Treasury Stock

During the nine months ended September 30, 2021, Entergy Corporation issued 465,135 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, 2021.

Retained Earnings

On October 29, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.01 per share, payable on December 1, 2021, to holders of record as of November 15, 2021.

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Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2021 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, 2021($1,083)($489,511)$11,855 ($478,739)
Other comprehensive income (loss) before reclassifications(14)— (2,173)(2,187)
Amounts reclassified from accumulated other comprehensive income (loss)38 8,838 11 8,887 
Net other comprehensive income (loss) for the period24 8,838 (2,162)6,700 
Ending balance, September 30, 2021($1,059)($480,673)$9,693 ($472,039)

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 nine months ended September 30, 2021 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, 2021$28,719 ($534,576)$56,650 ($449,207)
Other comprehensive income (loss) before reclassifications1,454 — (46,826)(45,372)
Amounts reclassified from accumulated other comprehensive income (loss)(31,232)53,903 (131)22,540 
Net other comprehensive income (loss) for the period(29,778)53,903 (46,957)(22,832)
Ending balance, September 30, 2021
($1,059)($480,673)$9,693 ($472,039)

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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Notes to Financial Statements

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2021 and 2020:

Pension and Other
Postretirement Liabilities
20212020
(In Thousands)
Beginning balance, July 1,$4,508 $13,084 
Amounts reclassified from accumulated other comprehensive income (loss)(131)(800)
Net other comprehensive income (loss) for the period(131)(800)
Ending balance, September 30,
$4,377 $12,284 

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2021 and 2020:
Pension and Other
Postretirement Liabilities
20212020
(In Thousands)
Beginning balance, January 1,$4,327 $4,562 
Other comprehensive income (loss) before reclassifications— 10,050 
Amounts reclassified from accumulated other comprehensive income (loss)50 (2,328)
Net other comprehensive income (loss) for the period50 7,722 
Ending balance, September 30,
$4,377 $12,284 

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2021 and 2020 were as follows:

Amounts reclassified
from AOCI		Income Statement Location
20212020
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$— $14,724 Competitive business operating revenues
   Interest rate swaps(48)(48)Miscellaneous - net
Total realized gain (loss) on cash flow hedges(48)14,676 
Income taxes10 (3,082)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)($38)$11,594 
Pension and other postretirement liabilities
   Amortization of prior-service credit$5,248 $5,682 (a)
   Amortization of loss(13,490)(27,620)(a)
   Settlement loss(3,192)(196)(a)
Total amortization(11,434)(22,134)
Income taxes2,596 4,697 Income taxes
Total amortization (net of tax)($8,838)($17,437)
Net unrealized investment gain (loss)
Realized gain (loss)($17)$4,550 Interest and investment income
Income taxes6 (1,674)Income taxes
Total realized investment gain (loss) (net of tax)($11)$2,876 
Total reclassifications for the period (net of tax)($8,887)($2,967)

(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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Notes to Financial Statements
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2021 and 2020 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20212020
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$39,679 $134,233 Competitive business operating revenues
   Interest rate swaps(145)(145)Miscellaneous - net
Total realized gain (loss) on cash flow hedges39,534 134,088 
Income taxes(8,302)(28,158)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)$31,232 $105,930 
Pension and other postretirement liabilities
   Amortization of prior-service credit$15,744 $15,083 (a)
   Amortization of loss(75,553)(82,561)(a)
   Settlement loss(9,235)(196)(a)
Total amortization(69,044)(67,674)
Income taxes15,141 13,463 Income taxes
Total amortization (net of tax)($53,903)($54,211)
Net unrealized investment gain (loss)
Realized gain (loss)$207 $13,963 Interest and investment income
Income taxes(76)(5,138)Income taxes
Total realized investment gain (loss) (net of tax)$131 $8,825 
Total reclassifications for the period (net of tax)($22,540)$60,544 

(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, 2021 and 2020 were as follows:

Amounts reclassified
from AOCI		Income Statement Location
20212020
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$1,230 $1,695 (a)
   Amortization of loss(519)(417)(a)
   Settlement loss(534)(196)(a)
Total amortization177 1,082 
Income taxes(46)(282)Income taxes
Total amortization (net of tax)131 800 
Total reclassifications for the period (net of tax)$131 $800 

(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, 2021 and 2020 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20212020
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$3,690 $4,479 (a)
   Amortization of loss(1,824)(1,137)(a)
   Settlement loss(1,934)(196)(a)
Total amortization(68)3,146 
Income taxes18 (818)Income taxes
Total amortization (net of tax)(50)2,328 
Total reclassifications for the period (net of tax)($50)$2,328 

(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.

Preferred Stock

In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of September 30, 2021, no preferred stock has been issued.

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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 June 2026.  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, 2021 was 1.60% 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, 2021.
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$325$6$3,169

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, 2021, Entergy Corporation had approximately $1,006 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2021 was 0.30%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2021 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate (a)Amount Drawn
as of
September 30, 2021		Letters of Credit
Outstanding as of
September 30, 2021
Entergy ArkansasApril 2022$25 million (b)2.75%$—$—
Entergy ArkansasJune 2026$150 million (c)1.21%$—$—
Entergy LouisianaJune 2026$350 million (c)1.33%$—$—
Entergy MississippiApril 2022$37.5 million (d)1.58%$—$—
Entergy MississippiApril 2022$35 million (d)1.58%$—$—
Entergy MississippiApril 2022$10 million (d)1.58%$—$—
Entergy New OrleansJune 2024$25 million (c)1.71%$25 million$—
Entergy TexasJune 2026$150 million (c)1.58%$—$1.3 million

(a)If no borrowings were outstanding, the interest rate is the estimated interest rate as of September 30, 2021 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.
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(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 0.375% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities 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, 2021:
CompanyAmount of
Uncommitted Facility		Letter of Credit FeeMISO Letters of Credit
Issued as of
September 30, 2021 (a) (b)
Entergy Arkansas$25 million0.78%$2 million
Entergy Louisiana$125 million 0.78%$6.8 million
Entergy Mississippi$65 million0.78%$2.3 million
Entergy New Orleans$15 million1.00%$1 million
Entergy Texas$50 million0.70%$12 million

(a)As of September 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $1.5 million for Entergy Louisiana, $0.7 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $0.8 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of September 30, 2021, in addition to the $2.3 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$175$35
Entergy New Orleans$150$—
Entergy Texas$200$20
System Energy$200$—

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Notes to Financial Statements
Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2021, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2021 was 1.69% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

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, 2021:
CompanyExpiration
Date 		Amount
of
Facility		Weighted
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
September 30, 2021
(Dollars in Millions)
Entergy Arkansas VIEJune 2024$801.20%$5.3
Entergy Louisiana River Bend VIEJune 2024$1051.17%$53.2
Entergy Louisiana Waterford VIEJune 2024$1051.18%$49.3
System Energy VIEJune 2024$1201.18%$40.7

(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 0.100% 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, 2021 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
3.17% Series M due December 2023
$40 million
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
3.22% Series I due December 2023
$20 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

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Entergy Arkansas, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

In October 2021, Entergy Louisiana issued $1 billion of 0.95% Series mortgage bonds due October 2024. Entergy Louisiana expects to use the proceeds, together with other funds, to finance, on an interim basis, storm restoration costs related to Hurricane Ida.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

In August 2021, Entergy Texas issued $130 million of 1.50% Series mortgage bonds due September 2026.
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Entergy Texas used the proceeds to repay at maturity its $75 million of 4.10% Series mortgage bonds due September 2021, and for general corporate purposes.

(System Energy)

In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2021 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$24,617,004 $26,151,363 
Entergy Arkansas$3,959,194 $4,211,956 
Entergy Louisiana$9,813,493 $10,622,419 
Entergy Mississippi$1,981,945 $2,154,281 
Entergy New Orleans$662,079 $611,728 
Entergy Texas$2,353,742 $2,510,669 
System Energy$745,772 $762,981 

(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, 2020 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$22,369,776 $24,813,818 
Entergy Arkansas$3,967,507 $4,355,632 
Entergy Louisiana$9,027,451 $10,258,294 
Entergy Mississippi$1,780,577 $2,021,432 
Entergy New Orleans$642,233 $620,634 
Entergy Texas$2,493,708 $2,765,193 
System Energy$805,274 $840,540 

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


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Notes to Financial Statements
NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

Stock Options

Entergy granted options on 508,704 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2021 with a fair value of $12.27 per option.  As of September 30, 2021, there were options on 2,824,144 shares of common stock outstanding with a weighted-average exercise price of $90.79.  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, 2021.  The aggregate intrinsic value of the stock options outstanding as of September 30, 2021 was $40.3 million.

The following table includes financial information for outstanding stock options for the three months ended September 30, 2021 and 2020:
20212020
(In Millions)
Compensation expense included in Entergy’s net income$1.2 $1.0 
Tax benefit recognized in Entergy’s net income$0.3 $0.3 
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, 2021 and 2020:
20212020
(In Millions)
Compensation expense included in Entergy’s net income$3.2 $3.0 
Tax benefit recognized in Entergy’s net income$0.8 $0.8 
Compensation cost capitalized as part of fixed assets and materials and supplies$1.2 $1.2 

Other Equity Awards

In January 2021 the Board approved and Entergy granted 392,382 restricted stock awards and 203,983 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 28, 2021 and were valued at $95.87 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. To emphasize the importance of strong cash generation for the long-term health of its business, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 performance period. Performance will be measured based eighty
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percent on relative total shareholder return and twenty percent on the credit measure.  The performance units were granted on January 28, 2021 and eighty percent were valued at $110.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $95.87 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.

The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2021 and 2020:
20212020
(In Millions)
Compensation expense included in Entergy’s net income$10.6 $8.9 
Tax benefit recognized in Entergy’s net income$2.7 $2.2 
Compensation cost capitalized as part of fixed assets and materials and supplies$4.1 $3.6 

The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2021 and 2020:
20212020
(In Millions)
Compensation expense included in Entergy’s net income$31.1 $27.9 
Tax benefit recognized in Entergy’s net income$7.9 $7.1 
Compensation cost capitalized as part of fixed assets and materials and supplies$12.1 $10.8 


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 2021 and 2020, included the following components:
20212020
(In Thousands)
Service cost - benefits earned during the period$38,531 $40,366 
Interest cost on projected benefit obligation49,222 59,930 
Expected return on assets(106,684)(103,534)
Amortization of net loss69,386 87,516 
Settlement charges44,718 32,429 
Net pension costs$95,173 $116,707 

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Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2021 and 2020, included the following components:
20212020
(In Thousands)
Service cost - benefits earned during the period$126,722 $121,124 
Interest cost on projected benefit obligation142,702 181,528 
Expected return on assets(318,437)(310,664)
Amortization of net loss266,576 262,034 
Settlement charges156,266 32,429 
Net pension costs$373,829 $286,451 

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2021 and 2020, included the following components:

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$6,966 $9,230 $2,197 $735 $1,680 $2,141 
Interest cost on projected benefit obligation9,396 10,270 2,735 1,156 2,213 2,379 
Expected return on assets(19,585)(22,466)(5,629)(2,678)(5,341)(4,853)
Amortization of net loss16,100 15,201 4,580 1,656 2,815 4,135 
Settlement charges7,238 13,209 3,685 1,107 1,634 4,086 
Net pension cost$20,115 $25,444 $7,568 $1,976 $3,001 $7,888 

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 
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The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2021 and 2020, included the following components:

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$21,640 $29,033 $6,865 $2,304 $5,237 $6,707 
Interest cost on projected benefit obligation26,488 29,695 7,769 3,264 6,215 6,757 
Expected return on assets(58,896)(67,521)(16,815)(7,941)(15,851)(14,436)
Amortization of net loss53,652 52,294 15,556 5,996 9,941 14,393 
Settlement charges31,624 48,201 11,447 4,691 8,261 8,725 
Net pension cost$74,508 $91,702 $24,822 $8,314 $13,803 $22,146 

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 

Non-Qualified Net Pension Cost

Entergy recognized $6.9 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2021 and 2020, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2021 were settlement charges of $2.5 million related to the payment of lump sum benefits out of the plan. Entergy recognized $16 million and $13.6 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2021 and 2020. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2021 were settlement charges of $2.5 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 2021 and 2020:

Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2021$86 $192 $91 $7 $115 
2020$83 $37 $90 $7 $118 

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Reflected in Entergy Louisiana’s non-qualified pension costs in the third quarter of 2021 were settlement charges of $155 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the third quarter of 2021 were settlement charges of $3 thousand related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2021 and 2020:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2021$266 $280 $283 $23 $345 
2020$249 $111 $270 $21 $354 

Reflected in Entergy Louisiana’s non-qualified pension costs for the nine months ended September 30, 2021 were settlement charges of $155 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2021 were settlement charges of $3 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 income, including amounts capitalized, for the third quarters of 2021 and 2020, included the following components:

20212020
(In Thousands)
Service cost - benefits earned during the period$6,645 $6,231 
Interest cost on accumulated postretirement benefit obligation (APBO)5,320 6,888 
Expected return on assets(10,805)(10,182)
Amortization of prior service credit(8,267)(8,985)
Amortization of net loss713 1,005 
Net other postretirement benefit income($6,394)($5,043)

Entergy’s other postretirement benefit cost income, including amounts capitalized, for the nine months ended September 30, 2021 and 2020, included the following components:
 20212020
 (In Thousands)
Service cost - benefits earned during the period$19,935 $18,263 
Interest cost on accumulated postretirement benefit obligation (APBO)15,960 21,708 
Expected return on assets(32,415)(30,692)
Amortization of prior service credit(24,801)(23,892)
Amortization of net loss2,139 2,478 
Net other postretirement benefit income($19,182)($12,135)

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The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the third quarters of 2021 and 2020, included the following components:

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,034 $1,544 $362 $109 $346 $335 
Interest cost on APBO932 1,130 278 130 317 220 
Expected return on assets(4,505)— (1,384)(1,438)(2,548)(789)
Amortization of prior service credit(280)(1,230)(444)(229)(936)(109)
Amortization of net (gain) loss49 (91)19 (178)100 15 
Net other postretirement benefit cost (income) ($2,770)$1,353 ($1,169)($1,606)($2,721)($328)

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)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2021 and 2020, included the following components:

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$3,102 $4,632 $1,086 $327 $1,038 $1,005 
Interest cost on APBO2,796 3,390 834 390 951 660 
Expected return on assets(13,515)— (4,152)(4,314)(7,644)(2,367)
Amortization of prior service credit(840)(3,690)(1,332)(687)(2,808)(327)
Amortization of net (gain) loss147 (273)57 (534)300 45 
Net other postretirement benefit cost (income)($8,310)$4,059 ($3,507)($4,818)($8,163)($984)

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2020Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,761 $2,947 $723 $219 $609 $615 
Interest cost on APBO2,381 3,220 794 413 1,059 583 
Expected return on assets(8,586)— (2,594)(2,699)(4,838)(1,483)
Amortization of prior service credit(1,057)(2,784)(765)(304)(1,489)(501)
Amortization of net (gain) loss217 (280)77 (29)443 53 
Net other postretirement benefit cost (income)($5,284)$3,103 ($1,765)($2,400)($4,216)($733)

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 2021 and 2020:

2021Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $5,288 ($40)$5,248 
Amortization of net loss(12,439)(496)(555)(13,490)
Settlement loss(2,731)— (461)(3,192)
($15,170)$4,792 ($1,056)($11,434)
Entergy Louisiana
Amortization of prior service credit$— $1,230 $— $1,230 
Amortization of net gain (loss)(609)91 (1)(519)
Settlement loss(528)— (6)($534)
($1,137)$1,321 ($7)$177 
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2020Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $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 

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, 2021 and 2020:
2021Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $15,864 ($120)$15,744 
Amortization of net loss(72,322)(1,486)(1,745)(75,553)
Settlement loss(8,774)— (461)(9,235)
($81,096)$14,378 ($2,326)($69,044)
Entergy Louisiana
Amortization of prior service credit$— $3,690 $— $3,690 
Amortization of net gain (loss)(2,093)273 (4)(1,824)
Settlement loss(1,928)— (6)(1,934)
($4,021)$3,963 ($10)($68)

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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 

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), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer 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 are eligible to participate in a health 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 were reflected in the March 31, 2020 other postretirement obligation.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs. Similar to other pension costs, 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, Entergy Mississippi, and Entergy New Orleans 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.

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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. At September 30, 2021, the balance in this reserve was approximately $11.8 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of September 30, 2021, Entergy had contributed $347.7 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 2021:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2021 pension contributions$66,649 $59,882 $13,715 $5,395 $6,955 $18,663 
Pension contributions made through September 2021$64,666 $59,422 $13,715 $5,395 $6,631 $18,006 
Remaining estimated pension contributions to be made in 2021$1,983 $460 $— $— $324 $657 

In October 2021, Entergy contributed the remaining $8.3 million to its qualified pension plans to satisfy the expected 2021 pension contributions.


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

Entergy’s reportable segments as of September 30, 2021 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.  See Note 13 to the financial statements in the Form 10-K for discussion of the shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown of Palisades, the only remaining plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of September 30, 2021. “All Other” includes the parent company, Entergy Corporation, and other business activity.

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Entergy’s segment financial information for the third quarters of 2021 and 2020 were as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsEntergy
(In Thousands)
2021
Operating revenues$3,191,240 $162,275 $24 ($7)$3,353,532 
Income taxes$159,472 $8,836 ($10,026)$— $158,282 
Consolidated net income (loss)$574,399 $26,064 ($32,982)($31,898)$535,583 
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 

Entergy’s segment financial information for the nine months ended September 30, 2021 and 2020 were as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsConsolidated
(In Thousands)
2021
Operating revenues$8,461,241 $559,150 $77 ($28)$9,020,440 
Income taxes$290,566 ($47,299)($37,459)$— $205,808 
Consolidated net income (loss)$1,264,933 ($210,460)($85,445)($95,695)$873,333 
Total assets as of September 30, 2021$58,948,010 $1,238,200 $698,699 ($2,041,410)$58,843,499 
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 December 31, 2020$55,940,153 $3,800,378 $552,632 ($2,053,951)$58,239,212 

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.

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 its 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.

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Total restructuring charges for the third quarters of 2021 and 2020 were comprised of the following:
20212020
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,$33 $— $33 $153 $14 $167 
Restructuring costs accrued2 — 2 19 — 19 
Cash paid out— — — 1 — 1 
Balance as of September 30,$35 $— $35 $171 $14 $185 

In addition, Entergy Wholesale Commodities incurred $4 million in the third quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. No charges were incurred in the third quarter 2021.

Total restructuring charges for the nine months ended September 30, 2021 and 2020 were comprised of the following:
20212020
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,$145 $14 $159 $129 $14 $143 
Restructuring costs accrued9 1 10 57 — 57 
Cash paid out119 15 134 15 — 15 
Balance as of September 30,$35 $— $35 $171 $14 $185 

In addition, Entergy Wholesale Commodities incurred $345 million in the nine months ended September 30, 2021 and $16 million in the nine months ended September 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions.

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 $10 million in 2021, of which $9 million has been incurred as of September 30, 2021, and a total of approximately $5 million in 2022.
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Notes to Financial Statements

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 entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

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 entered 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 settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 1.7 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed 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. 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.  As of September 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by counterparties to the Entergy subsidiary.   

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, 2021 was 2.5 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of September 30, 2021 was 6 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2021 was 30,980,500 MMBtu for Entergy, including 18,260,000 MMBtu for Entergy Louisiana, 11,438,000 MMBtu for Entergy Mississippi, and 1,282,500 MMBtu for Entergy New 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.

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During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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, 2021 was 91,873 GWh for Entergy, including 19,386 GWh for Entergy Arkansas, 41,531 GWh for Entergy Louisiana, 10,505 GWh for Entergy Mississippi, 4,242 GWh for Entergy New Orleans, and 15,849 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. As of September 30, 2021, $6 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of September 30, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2021 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 not designated as hedging instruments
Assets:
Natural gas swaps and optionsPrepayments and other (current portion)$39$—$39Utility
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$8$—$8Utility
Financial transmission rightsPrepayments and other$8$—$8Utility and Entergy Wholesale Commodities
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The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 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)$39($1)$38Entergy Wholesale Commodities
Liabilities:    
Electricity swaps and optionsOther current liabilities (current portion)$1($1)$—Entergy Wholesale Commodities
Derivatives not designated as hedging instruments    
Assets:    
Natural gas swaps and optionsPrepayments and other (current portion)$1$—$1Utility
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$1$—$1Utility
Financial transmission rightsPrepayments and other$9$—$9Utility and Entergy Wholesale Commodities
Liabilities:    
Natural gas swaps and optionsOther current liabilities (current portion)$6$—$6Utility
Natural gas swaps and optionsOther non-current liabilities (non-current portion)$1$—$1Utility

(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 $6 million posted as of September 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $4 million posted as of September 30, 2021 and $1 million posted and $39 million held as of December 31, 2020.
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The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2021 and 2020 were as follows:
InstrumentAmount of gain (loss)
recognized in other
comprehensive
income		Income Statement locationAmount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a)
(In Millions)(In Millions)
2021
Electricity swaps and options$—Competitive businesses operating revenues$—
2020
Electricity swaps and options($6)Competitive businesses operating revenues$15

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

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2021 and 2020 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)
2021
Electricity swaps and options$2Competitive businesses operating revenues$40
2020
Electricity swaps and options$54Competitive businesses operating revenues$134

(a)Before taxes of $8 million and $28 million for the nine months ended September 30, 2021 and 2020, respectively

Based on market prices as of September 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales.

Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings.
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The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2021 and 2020 were as follows:
InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2021
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$37
Financial transmission rightsPurchased power expense(b)$18
Electricity swaps and options (c)Competitive business operating revenues$—
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

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2021 and 2020 were as follows:
InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale(a)$62
Financial transmission rightsPurchased power expense(b)$162
Electricity swaps and options (c)Competitive business operating revenues($2)
2020
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$61
Electricity swaps and options (c)Competitive business operating revenues$—

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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, 2021 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$19.6$—$19.6Entergy Louisiana
Natural gas swaps and optionsOther deferred debits and other assets (non-current portion)$2.3$—$2.3Entergy Louisiana
Natural gas swapsPrepayments and other$23.2$—$23.2Entergy Mississippi
Natural gas swapsPrepayments and other$2.3$—$2.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.4$—$2.4Entergy Arkansas
Financial transmission rightsPrepayments and other$2.7($0.1)$2.6Entergy Louisiana
Financial transmission rightsPrepayments and other$0.6$—$0.6Entergy Mississippi
Financial transmission rightsPrepayments and other$0.3$—$0.3
Entergy New Orleans
Financial transmission rightsPrepayments and other$1.7$—$1.7Entergy Texas

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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, 2020 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 optionsPrepayments and other $0.8$—$0.8Entergy Louisiana
Natural gas swaps and optionsOther deferred debits and other assets$0.5$—$0.5Entergy Louisiana
Financial transmission rightsPrepayments and other$2.9($0.2)$2.7Entergy Arkansas
Financial transmission rightsPrepayments and other$4.3($0.1)$4.2Entergy Louisiana
Financial transmission rightsPrepayments and other$0.6$—$0.6Entergy Mississippi
Financial transmission rightsPrepayments and other$0.2($0.1)$0.1Entergy New Orleans
Financial transmission rightsPrepayments and other$1.6$—$1.6Entergy Texas
Liabilities:
Natural gas swaps and optionsOther current liabilities$0.3$—$0.3Entergy Louisiana
Natural gas swaps and optionsOther non-current liabilities$1.3$—$1.3Entergy Louisiana
Natural gas swapsOther current liabilities$5.0$—$5.0Entergy Mississippi
Natural gas swapsOther current liabilities$0.3$—$0.3Entergy 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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $1.5 million for Entergy Louisiana, $0.7 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $0.8 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for 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 three months ended September 30, 2021 and 2020 were as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$9.4(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$25.6(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.2(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$8.7(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$1.5(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$0.6(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.6(b)Entergy Texas
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
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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, 2021 and 2020 were as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$16.1(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$44(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.2(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$34(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$26.8(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$9.4(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$2.6(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$85.3(b)Entergy Texas
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)(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

(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 reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various
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inputs and 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, 2021 and December 31, 2020.  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.
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$956 $— $— $956 
Decommissioning trust funds (a):
Equity securities100 — — 100 
Debt securities (b)733 1,322 — 2,055 
Common trusts (c)3,081 
Securitization recovery trust account28 — — 28 
Escrow accounts49 — — 49 
Gas hedge contracts39 8 — 47 
Financial transmission rights— — 8 8 
$1,905 $1,330 $8 $6,324 

2020Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$1,630 $— $— $1,630 
Decommissioning trust funds (a):    
Equity securities1,533 — — 1,533 
Debt securities (b)919 1,698 — 2,617 
Common trusts (c)3,103 
Power contracts— — 38 38 
Securitization recovery trust account42 — — 42 
Escrow accounts148 — — 148 
Gas hedge contracts1 1 — 2 
Financial transmission rights— — 9 9 
 $4,273 $1,699 $47 $9,122 
Liabilities:    
Gas hedge contracts$6 $1 $— $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.
(b)The decommissioning trust funds fair values presented herein do not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.3 million as of September 30, 2021 and $0.1 million as of December 31, 2020 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.
(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
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The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2021 and 2020:
20212020
Power ContractsFinancial transmission rightsPower ContractsFinancial transmission rights
(In Millions)
Balance as of July 1,$— $15 $49 $22 
Total gains (losses) for the period (a)
Included in earnings— — 2 1 
Included in other comprehensive income— — (6)— 
Included as a regulatory liability/asset— 11 — 27 
Settlements— (18)(17)(33)
Balance as of September 30,$— $8 $28 $17 

(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.

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, 2021 and 2020:
20212020
Power ContractsFinancial transmission rightsPower ContractsFinancial transmission rights
(In Millions)
Balance as of January 1,$38 $9 $118 $10 
Total gains (losses) for the period (a)
Included in earnings(2)— — 1 
Included in other comprehensive income2 — 54 — 
Included as a regulatory liability/asset— 149 — 44 
Issuances of financial transmission rights— 12 — 23 
Settlements(38)(162)(144)(61)
Balance as of September 30,$— $8 $28 $17 

(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.
The fair values of the Level 3 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)
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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, 2021 and December 31, 2020.  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
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$96.5 $— $— $96.5 
Decommissioning trust funds (a):
Equity securities71.2 — — 71.2 
Debt securities124.7 353.2 — 477.9 
Common trusts (b)827.2 
Financial transmission rights— — 2.4 2.4 
$292.4 $353.2 $2.4 $1,475.2 

2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$168.0 $— $— $168.0 
Decommissioning trust funds (a):
Equity securities1.3 — — 1.3 
Debt securities98.2 349.7 — 447.9 
Common trusts (b)824.7 
Financial transmission rights— — 2.7 2.7 
$267.5 $349.7 $2.7 $1,444.6 

Entergy Louisiana
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$266.3 $— $— $266.3 
Decommissioning trust funds (a):
Equity securities13.3 — — 13.3 
Debt securities218.1 487.7 — 705.8 
Common trusts (b)1,268.2 
Securitization recovery trust account5.5 — — 5.5 
Gas hedge contracts19.6 2.3 — 21.9 
Financial transmission rights— — 2.6 2.6 
$522.8 $490.0 $2.6 $2,283.6 

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2020Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$726.7 $— $— $726.7 
Decommissioning trust funds (a):    
Equity securities8.7 — — 8.7 
Debt securities172.4 459.8 — 632.2 
Common trusts (b)1,153.1 
Securitization recovery trust account2.7 — — 2.7 
Gas hedge contracts0.8 0.5 — 1.3 
Financial transmission rights— — 4.2 4.2 
 $911.3 $460.3 $4.2 $2,528.9 
Liabilities:
Gas hedge contracts$0.3 $1.3 $— $1.6 

Entergy Mississippi
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Escrow accounts$48.9 $— $— $48.9 
Gas hedge contracts23.2 — — 23.2 
Financial transmission rights— — 0.6 0.6 
$72.1 $— $0.6 $72.7 

2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Escrow accounts$64.6 $— $— $64.6 
Financial transmission rights— — 0.6 0.6 
 $64.6 $— $0.6 $65.2 
Liabilities:
Gas hedge contracts$5.0 $— $— $5.0 

Entergy New Orleans
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$26.4 $— $— $26.4 
Securitization recovery trust account5.7 — — 5.7 
Gas hedge contracts2.3 — — 2.3 
Financial transmission rights— — 0.3 0.3 
$34.4 $— $0.3 $34.7 

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2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Securitization recovery trust account$3.4 $— $— $3.4 
Escrow accounts83.0 — — 83.0 
Financial transmission rights— — 0.1 0.1 
$86.4 $— $0.1 $86.5 
Liabilities:
Gas hedge contracts$0.3 $— $— $0.3 

Entergy Texas
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Securitization recovery trust account$17.2 $— $— $17.2 
Financial transmission rights— — 1.7 1.7 
$17.2 $— $1.7 $18.9 

2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$248.6 $— $— $248.6 
Securitization recovery trust account36.2 — — 36.2 
Financial transmission rights— — 1.6 1.6 
$284.8 $— $1.6 $286.4 
System Energy
2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$163.0 $— $— $163.0 
Decommissioning trust funds (a):
Equity securities5.1 — — 5.1 
Debt Securities219.3 248.7 — 468.0 
Common trusts (b)837.4 
$387.4 $248.7 $— $1,473.5 

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2020Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$216.4 $— $— $216.4 
Decommissioning trust funds (a):
Equity securities3.8 — — 3.8 
Debt securities177.3 250.4 — 427.7 
Common trusts (b)784.4 
$397.5 $250.4 $— $1,432.3 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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, 2021.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of July 1,$3.8 $4.8 $2.1 $0.6 $3.8 
Gains (losses) included as a regulatory liability/asset3.1 6.5 — 0.3 0.5 
Settlements(4.5)(8.7)(1.5)(0.6)(2.6)
Balance as of September 30,$2.4 $2.6 $0.6 $0.3 $1.7 

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 nine months ended September 30, 2021.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$2.7 $4.2 $0.6 $0.1 $1.6 
Issuances of financial transmission rights2.8 4.1 1.7 0.4 2.7 
Gains (losses) included as a regulatory liability/asset30.9 21.1 7.7 2.4 82.7 
Settlements(34.0)(26.8)(9.4)(2.6)(85.3)
Balance as of September 30,$2.4 $2.6 $0.6 $0.3 $1.7 

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 


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

As discussed in Note 14 to the financial statements herein, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million.

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
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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 were 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 were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. 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, 2021 on equity securities still held as of September 30, 2021 were ($22) million and $359 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, 2021 and December 31, 2020 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2021
Debt Securities$2,055 $74 $10 
2020
Debt Securities$2,617 $197 $3 

The unrealized gains/(losses) above are reported before deferred taxes of $4 million as of September 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,992 million as of September 30, 2021 and $2,423 million as of December 31, 2020.  As of September 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.73%, an average duration of approximately 6.76 years, and an average maturity of approximately 10.36 years.

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, 2021 and December 31, 2020:
September 30, 2021December 31, 2020
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$650 $9 $187 $3 
More than 12 months35 1 2 — 
Total$685 $10 $189 $3 
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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2021 and December 31, 2020 were as follows:
20212020
(In Millions)
Less than 1 year$— ($4)
1 year - 5 years431 672 
5 years - 10 years679 852 
10 years - 15 years346 377 
15 years - 20 years122 144 
20 years+477 576 
Total$2,055 $2,617 

During the three months ended September 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $354 million and $156 million, respectively.  During the three months ended September 30, 2021 and 2020, gross gains of $8 million and $9 million, respectively, and gross losses of $2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $1,151 million and $832 million, respectively.  During the nine months ended September 30, 2021 and 2020, gross gains of $24 million and $38 million, respectively, and gross losses of $15 million and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of September 30, 2021 was $562 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2021 and December 31, 2020 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2021
Debt Securities$477.9 $13.3 $3.4 
2020
Debt Securities$447.9 $27.7 $0.3 

The amortized cost of available-for-sale debt securities was $468 million as of September 30, 2021 and $420.4 million as of December 31, 2020.  As of September 30, 2021, available-for-sale debt securities had an
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average coupon rate of approximately 2.26%, an average duration of approximately 6.10 years, and an average maturity of approximately 7.16 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2021 on equity securities still held as of September 30, 2021 were ($8) million and $93.9 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, 2021 and December 31, 2020:
September 30, 2021December 31, 2020
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$171.1 $2.6 $29.9 $0.3 
More than 12 months17.5 0.8 — — 
Total$188.6 $3.4 $29.9 $0.3 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2021 and December 31, 2020 were as follows:
 20212020
 (In Millions)
Less than 1 year$— $— 
1 year - 5 years74.2 113.1 
5 years - 10 years207.3 189.8 
10 years - 15 years131.6 81.4 
15 years - 20 years31.3 28.5 
20 years+33.5 35.1 
Total$477.9 $447.9 

During the three months ended September 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $20.6 million and $14.6 million, respectively.  During the three months ended September 30, 2021 and 2020, gross gains of $0.7 million and $1.7 million, respectively, and gross losses of $0.2 million and $3.6 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, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $46.7 million and $80.9 million, respectively.  During the nine months ended September 30, 2021 and 2020, gross gains of $2.3 million and $7.5 million, respectively, and gross losses of $0.3 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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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, 2021 and December 31, 2020 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2021
Debt Securities$705.8 $33.1 $3.3 
2020
Debt Securities$632.2 $51.3 $0.5 

The amortized cost of available-for-sale debt securities was $676 million as of September 30, 2021 and $581.4 million as of December 31, 2020.  As of September 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.42%, an average duration of approximately 6.74 years, and an average maturity of approximately 12.29 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2021 on equity securities still held as of September 30, 2021 were ($6.7) million and $150.6 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, 2021 and December 31, 2020:
September 30, 2021December 31, 2020
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$173.2 $2.6 $36.4 $0.5 
More than 12 months15.0 0.7 0.8 — 
Total$188.2 $3.3 $37.2 $0.5 

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2021 and December 31, 2020 were as follows:
20212020
(In Millions)
Less than 1 year$— $— 
1 year - 5 years117.0 117.0 
5 years - 10 years191.0 159.4 
10 years - 15 years109.5 101.2 
15 years - 20 years77.6 66.9 
20 years+210.7 187.7 
Total$705.8 $632.2 

During the three months ended September 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $20.5 million and $30.6 million, respectively.  During the three months ended September 30, 2021 and 2020, gross gains of $0.9 million and $1.4 million, respectively, and gross losses of $23.5 thousand and $1.3 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, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $191.4 million and $132.1 million, respectively.  During the nine months ended September 30, 2021 and 2020, gross gains of $5.6 million and $6.3 million, respectively, and gross losses of $3.4 million and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2021 and December 31, 2020 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2021
Debt Securities$468.0 $12.5 $2.4 
2020
Debt Securities$427.7 $30.0 $0.8 

The amortized cost of available-for-sale debt securities was $458 million as of September 30, 2021 and $398.4 million as of December 31, 2020.  As of September 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 7.18 years, and an average maturity of approximately 10.18 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2021 on equity securities still held as of September 30, 2021 were ($7.1) million and $96.1 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.
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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, 2021 and December 31, 2020:
September 30, 2021December 31, 2020
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$200.6 $2.4 $28.9 $0.8 
More than 12 months1.4 — — — 
Total$202.0 $2.4 $28.9 $0.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2021 and December 31, 2020 were as follows:
20212020
(In Millions)
Less than 1 year$— ($1.1)
1 year - 5 years149.2 134.7 
5 years - 10 years147.0 141.5 
10 years - 15 years40.2 31.5 
15 years - 20 years1.2 5.3 
20 years+130.4 115.8 
Total$468.0 $427.7 

During the three months ended September 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $292.8 million and $24.1 million, respectively.  During the three months ended September 30, 2021 and 2020, gross gains of $5.9 million and $1.6 million, respectively, and gross losses of $2 million and $9.9 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, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $468.5 million and $189.7 million, respectively.  During the nine months ended September 30, 2021 and 2020, gross gains of $9 million and $8.6 million, respectively, and gross losses of $3.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.3 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three and nine months ended September 30, 2021 and 2020.
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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 authorities. 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,
2021202020212020
(In Millions)
Entergy$17 $17 $72 $61 
Entergy Arkansas$— ($2)$8 $9 
Entergy Louisiana$8 $8 $24 $24 
Entergy New Orleans$— $1 $— $6 
Entergy Texas$9 $10 $22 $22 
System Energy$— $— $18 $— 

Valuation Allowance

During the second quarter 2021, Entergy reduced a valuation allowance by $9 million recorded on the deferred tax asset for a carryover of interest expense because new information indicates that there is sufficient taxable income of a nature that allows for carryover utilization.


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, 2021 were $1,783 million for Entergy, $38.9 million for Entergy Arkansas, $1,552.9 million for Entergy Louisiana, $25.5 million for Entergy Mississippi, $77.6 million for Entergy New Orleans, $42.3 million for Entergy Texas, and $17.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.


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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, 2021 and in the three months ended September 30, 2020. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2021 and in the nine months ended September 30, 2020.


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, 2021 and 2020 were as follows:
20212020
(In Thousands)
Utility:
Residential$1,291,645 $1,153,220 
Commercial756,903 647,119 
Industrial814,685 589,648 
Governmental66,167 56,710 
    Total billed retail2,929,400 2,446,697 
Sales for resale (a)135,220 145,187 
Other electric revenues (b)81,343 69,122 
    Revenues from contracts with customers3,145,963 2,661,006 
Other revenues (c)14,006 5,799 
    Total electric revenues3,159,969 2,666,805 
Natural gas31,254 22,357 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)158,608 195,184 
Other revenues (c)3,701 19,222 
    Total competitive businesses revenues162,309 214,406 
    Total operating revenues$3,353,532 $2,903,568 



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Entergy’s total revenues for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Utility:
Residential$3,114,084 $2,742,118 
Commercial1,958,284 1,712,179 
Industrial2,169,295 1,723,367 
Governmental184,576 156,251 
    Total billed retail7,426,239 6,333,915 
Sales for resale (a)459,425 251,674 
Other electric revenues (b)348,683 288,009 
    Revenues from contracts with customers8,234,347 6,873,598 
Other revenues (c)105,417 34,401 
    Total electric revenues8,339,764 6,907,999 
Natural gas121,420 88,829 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)537,402 586,906 
Other revenues (c)21,854 159,800 
    Total competitive businesses revenues559,256 746,706 
    Total operating revenues$9,020,440 $7,743,534 

The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2021 and 2020 were as follows:
2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$294,797 $477,025 $184,479 $85,974 $249,370 
Commercial149,952 300,255 131,472 57,563 117,661 
Industrial155,714 477,439 40,671 8,574 132,287 
Governmental5,747 21,448 13,110 20,016 5,846 
    Total billed retail606,210 1,276,167 369,732 172,127 505,164 
Sales for resale (a)76,576 98,830 35,199 23,290 25,329 
Other electric revenues (b)33,120 27,790 13,689 (3,258)11,355 
Revenues from contracts with customers715,906 1,402,787 418,620 192,159 541,848 
Other revenues (c)6,777 4,950 1,699 787 (216)
    Total electric revenues722,683 1,407,737 420,319 192,946 541,632 
Natural gas— 12,971 — 18,283 — 
    Total operating revenues$722,683 $1,420,708 $420,319 $211,229 $541,632 
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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 customers
637,601 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 

The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2021 and 2020 were as follows:
2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$703,081 $1,153,428 $449,576 $212,586 $595,413 
Commercial367,556 787,255 331,052 156,454 315,967 
Industrial373,410 1,299,633 111,195 23,391 361,666 
Governmental14,538 61,611 34,526 54,708 19,193 
    Total billed retail1,458,585 3,301,927 926,349 447,139 1,292,239 
Sales for resale (a)256,411 253,600 119,559 40,796 118,944 
Other electric revenues (b)125,912 127,444 54,029 2,894 42,461 
Revenues from contracts with customers1,840,908 3,682,971 1,099,937 490,829 1,453,644 
Other revenues (c)15,435 59,008 6,041 1,026 (1,358)
    Total electric revenues1,856,343 3,741,979 1,105,978 491,855 1,452,286 
Natural gas— 53,971 — 67,449 — 
    Total operating revenues$1,856,343 $3,795,950 $1,105,978 $559,304 $1,452,286 

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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 customers
1,604,754 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 

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.
(c)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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the nine months ended September 30, 2021 and 2020.
EntergyEntergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of December 31, 2020$117.7 $18.3 $45.7 $19.5 $17.4 $16.8 
Provisions43.4 20.0 17.7 2.1 2.0 1.6 
Write-offs(72.5)(21.4)(28.3)(11.8)(1.3)(9.7)
Recoveries7.5 2.1 3.0 1.6 0.5 0.3 
Balance as of September 30, 2021$96.1 $19.0 $38.1 $11.4 $18.6 $9.0 

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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 
Provisions66.9 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 
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.


NOTE 14.  ACQUISITIONS AND DISPOSITIONS (Entergy Corporation and Entergy Texas)

Acquisitions

Hardin County Peaking Facility

In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $67.9 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $36.7 million.

Dispositions

Indian Point Energy Center

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 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets.

________________

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
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the interim periods presented.  Entergy’s business is subject to seasonal fluctuations, however, with peak periods occurring typically during the first and third quarters.  The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.


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

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

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of September 30, 2021, 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, 2021 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.



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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Arkansas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Arkansas were approximately $145 million in February 2021 compared to approximately $40 million in February 2020. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Arkansas.

In March 2021 the APSC opened an investigation into Arkansas utilities’ preparation, response, operational performance, and communication regarding the February 2021 extreme weather events. Comments from jurisdictional utilities were filed in August 2021. In April 2021 the Arkansas Attorney General notified utilities of its intent to conduct an investigation into the fuel costs that were charged during the February 2021 winter storms; specifically, whether there was price gouging by suppliers.

Results of Operations

Net Income

Third Quarter 2021 Compared to Third Quarter 2020

Net income increased $19 million primarily due to higher volume/weather and higher retail electric price, partially offset by higher depreciation and amortization expenses and higher other operation and maintenance expenses.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income increased $63.9 million primarily due to higher volume/weather, the reversal in 2021 of the remaining regulatory liability for the formula rate plan 2019 historical year netting adjustment, and higher retail electric price, partially offset by a higher effective income tax rate, higher depreciation and amortization expenses, and higher other operation and maintenance expenses.

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Operating Revenues

Third Quarter 2021 Compared to Third Quarter 2020

Following is an analysis of the change in operating revenues comparing the third quarter 2021 to the third quarter 2020:
Amount
(In Millions)
2020 operating revenues$644.4 
Fuel, rider, and other revenues that do not significantly affect net income37.9 
Volume/weather25.8 
Retail electric price14.6 
2021 operating revenues$722.7 

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 an increase of 433 GWh, or 7%, in billed electricity usage, primarily due to an increase in industrial usage and the effect of more favorable weather on residential sales. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of May 2021. See Note 2 to the financial statements herein for further discussion of the 2020 formula rate plan filing.

Billed electric energy sales for Entergy Arkansas for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential2,443 2,380 3 
Commercial1,664 1,619 3 
Industrial2,379 2,056 16 
Governmental65 63 3 
  Total retail 6,551 6,118 7 
Sales for resale:
  Associated companies642 520 23 
  Non-associated companies1,569 1,494 5 
Total8,762 8,132 8 

See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.

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Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:
Amount
(In Millions)
2020 operating revenues$1,618.1 
Fuel, rider, and other revenues that do not significantly affect net income146.8 
Volume/weather69.8 
Retail electric price21.6 
2021 operating revenues$1,856.3 

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 an increase of 1,302 GWh, or 8%, in billed electricity usage, primarily due to an increase in industrial usage and the effect of more favorable weather on residential sales. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of May 2021. See Note 2 to the financial statements herein for further discussion of the 2020 formula rate plan filing.

Billed electric energy sales for Entergy Arkansas for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential6,400 5,951 8 
Commercial4,189 4,079 3 
Industrial6,346 5,605 13 
Governmental171 169 1 
  Total retail 17,106 15,804 8 
Sales for resale:
  Associated companies1,763 1,232 43 
  Non-associated companies5,300 3,471 53 
Total24,169 20,507 18 

See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.

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Other Income Statement Variances

Third Quarter 2021 Compared to Third Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•the deferral in the third quarter 2020 of $3 million in estimated incremental bad debt expenses that were incurred in second quarter 2020 resulting from the COVID-19 pandemic. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity associated with the COVID-19 pandemic;
•an increase of $2.5 million in distribution operations expenses primarily due to a higher scope of work, including contract costs; and
•an increase of $2 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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.

The increase was partially offset by:

•a decrease of $1.6 million in meter reading expenses as a result of the deployment of advanced metering systems;
•a decrease of $1.3 million in energy efficiency expenses due to the timing of recovery from customers; and
•a decrease of $1.2 million in nuclear generation expenses primarily due to lower nuclear labor costs, including contract labor, and a lower scope of work performed in 2021 as compared to 2020.

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

Other regulatory charges (credits) - net for the third quarter 2020 included regulatory credits of $13.6 million to reflect the 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. Entergy Arkansas records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and trust earnings plus asset retirement obligation related costs collected in revenue. Entergy Arkansas recorded regulatory charges in the third quarter 2021 as a result of portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds.

Other income increased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds in the third quarter 2021.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $6 million in non-nuclear generation expenses due to a higher scope of work performed during plant outages in 2021 as compared to 2020;
•an increase of $5.9 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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
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herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;
•lower nuclear insurance refunds of $5.8 million;
•an increase of $3.9 million in distribution operations expenses primarily due to an increase in vegetation maintenance costs and higher contractor costs;
•the deferral in 2020 of $3 million in estimated incremental bad debt expenses resulting from the COVID-19 pandemic. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity associated with the COVID-19 pandemic;
•an increase of $2.4 million as a result of the amount of transmission costs allocated by MISO; and
•an increase of $2.1 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives.

The increase was partially offset by:

•a decrease of $5.1 million in nuclear generation expenses primarily due to lower nuclear labor costs, including contract labor, and a lower scope of work performed in 2021 as compared to 2020;
•a decrease of $4.6 million in meter reading expenses as a result of the deployment of advanced metering systems; and
•a decrease of $3.4 million in energy efficiency expenses due to the timing of recovery from customers.

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

Other regulatory charges (credits) - net for the nine months ended September 30, 2021 includes the reversal of the remaining $38.8 million regulatory liability for the 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. Other regulatory charges (credits) - net for the nine months ended September 30, 2020 included regulatory credits of $35.8 million to reflect the 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 2020 and 2019 formula rate plan filings. Entergy Arkansas records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and trust earnings plus asset retirement obligation related costs collected in revenue. Entergy Arkansas recorded regulatory charges in the third quarter 2021 as a result of portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds.

Other income increased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing for the ANO 1 and ANO 2 decommissioning trust funds in 2021.

Income Taxes

The effective income tax rate was 24.5% for the third quarter 2021. The difference in the effective income tax rate for the third quarter 2021 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 21.7% for the nine months ended September 30, 2021. The difference in the effective income tax rate for the nine months ended September 30, 2021 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 and the amortization of excess accumulated deferred income taxes. See Note 10 to the financial statements herein and Note 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 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
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statements herein and Note 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 Note 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 discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
 20212020
 (In Thousands)
Cash and cash equivalents at beginning of period$192,128 $3,519 
Cash flow provided by (used in):
Operating activities453,077 511,952 
Investing activities(546,953)(634,739)
Financing activities(915)717,172 
Net increase (decrease) in cash and cash equivalents(94,791)594,385 
Cash and cash equivalents at end of period$97,337 $597,904 

Operating Activities

Net cash flow provided by operating activities decreased $58.9 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•increased fuel costs, including those related to Winter Storm Uri, and the timing of recovery of fuel and purchased power costs. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;
•the timing of collections of receivables from customers, in part due to the COVID-19 pandemic;
•$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; and
•an increase of $21.6 million in pension contributions in 2021. 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 decrease was partially offset by the timing of payments to vendors.

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Investing Activities

Net cash flow used in investing activities decreased $87.8 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•a decrease of $72.1 million in storm spending;
•money pool activity;
•a decrease of $27.6 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 2021 as compared to 2020;
•a decrease of $23 million in information technology expenditures primarily due to decreased spending on various technology projects, including advanced metering infrastructure; and
•a decrease of $17.5 million in non-nuclear generation construction expenditures primarily due to a lower scope of work performed in 2021 as compared to 2020.

The decrease 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
•an increase of $27.9 million in distribution construction expenditures primarily due to a higher scope of work performed in 2021 as compared to 2020.

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 $4.2 million for the nine months ended September 30, 2021 compared to increasing by $51.7 million for the nine months ended September 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Entergy Arkansas’s financing activities used $0.9 million of cash for the nine months ended September 30, 2021 compared to providing $717.2 million for the nine months ended September 30, 2020 primarily due to the following activity:

•the issuance of $400 million of 3.35% Series mortgage bonds in March 2021 as compared to the 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;
•the repayment, at maturity, of $350 million of 3.75% Series mortgage bonds due February 2021;
•the repayment, at maturity, of $45 million of 2.375% governmental bonds due January 2021;
•higher prepaid deposits of $29.8 million related to contributions-in-aid-of-construction generation interconnection agreements in 2021 as compared to 2020; and
•money pool activity.

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.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

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Capital Structure

Entergy Arkansas’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to an increase in equity resulting from net income.
September 30,
2021		December 31,
2020
Debt to capital52.8 %54.8 %
Effect of subtracting cash(0.6 %)(1.2 %)
Net debt to net capital52.2 %53.6 %

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 ratio in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition.  Entergy Arkansas also 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 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 is developing its capital investment plan for 2022 through 2024 and currently anticipates making $2.6 billion in capital investments during that period. The preliminary estimate includes generation projects to modernize, decarbonize, and diversify Entergy Arkansas’s portfolio, such as the Walnut Bend Solar Facility and the West Memphis Solar Facility; investments in ANO 1 and 2; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:
September 30,
2021		December 31,
2020		September 30,
2020		December 31,
2019
(In Thousands)
$7,301$3,110$51,697($21,634)

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

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Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in June 2026. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 2022. 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, 2021, 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, 2021, a $2 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 June 2024.  As of September 30, 2021, $5.3 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 April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. Subject to the terms of the tax equity partnership, Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occur by the end of 2021.

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 primarily requested cost recovery through the formula rate plan rider. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2022.

West Memphis Solar Facility

In January 2021, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 180 MW West Memphis Solar Facility is in the public interest. In October 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the West Memphis Solar Facility and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2023.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery.  The following are updates to that discussion.

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Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.

2021 Formula Rate Plan Filing

In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. 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 exceeded the constraint, the resulting increase is limited to $72.4 million. In October 2021, Entergy Arkansas filed with the APSC a settlement agreement reached with other parties resolving all issues in the proceeding. As a result of the settlement agreement, the total proposed revenue change is $82.2 million, including a $62.8 million increase for the projected 2022 year and a $19.4 million netting adjustment. Because Entergy Arkansas’s revenue requirement exceeded the constraint, the resulting increase is limited to $72.1 million. Also in October 2021 the APSC issued an order canceling the evidentiary hearing, accepting all filed testimony and exhibits into the record, and excusing all witnesses. The APSC will rule on the settlement agreement at a later date.

Energy Cost Recovery Rider

As discussed in the Form 10-K, in January 2014, Entergy Arkansas filed a motion with the APSC relating to its energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator
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incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regarding various claims associated with the ANO stator incident. In February 2014 the APSC approved Entergy Arkansas’s request to retain that amount in its deferred fuel balance. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. See the “ANO Damage, Outage, and NRC Reviews” section in Note 8 to the financial statements in the Form 10-K for further discussion of the ANO stator incident.

In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 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. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.

Net Metering Legislation

See the Form 10-K for discussion of Arkansas net metering legislation and subsequent APSC net metering proceedings. In January 2021, Entergy Arkansas, pursuant to an APSC order, filed an updated net metering tariff, which was approved in February 2021. In May 2021, Entergy Arkansas filed a motion to dismiss its pending judicial appeal of the APSC’s September 2020 order on rehearing in the proceeding addressing its net metering rules. In June 2021 the Arkansas Court of Appeals granted the motion and dismissed Entergy Arkansas’s appeal, although other appeals of the September 2020 APSC order remain pending with that court.

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Green Promise Renewable Tariff

In July 2021, Entergy Arkansas filed a proposed green tariff designed to help participating customers meet their renewable and sustainability goals and to enhance economic development efforts in Arkansas. The total proposed amount of solar capacity currently available under this tariff is up to 200 MW. In September and October 2021 the APSC general staff and two net-metering solar developer intervenors filed responses indicating opposition to the tariff as proposed. The tariff is supported by certain commercial and industrial customers that have indicated an interest in subscribing to the tariff. In October 2021, Entergy Arkansas, Walmart, and industrial customers filed a non-unanimous settlement agreement supporting that the tariff should be approved as filed; the Arkansas Attorney General stated it does not oppose the settlement. A hearing is scheduled in January 2022.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. In August 2021 the APSC general staff filed a report recommending that utilities with a formula rate plan discontinue capturing any additional direct costs and savings as a regulatory asset and seek cost recovery through the formula rate plan. The APSC general staff further recommended that uncollectible amounts should be determined as of the end of its write-off period, approximately December 2021, and recovered in the next formula rate plan filing over one year. In November 2021 the APSC found the APSC general staff’s recommendation to be premature and asked utilities to report on the continued need for a regulatory asset. As of September 30, 2021, Entergy Arkansas had a regulatory asset of $24.5 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.

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, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$722,683 $644,389 $1,856,343 $1,618,068 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale94,580 77,239 295,317 217,342 
Purchased power74,579 57,599 206,248 145,811 
Nuclear refueling outage expenses13,207 13,010 39,389 42,809 
Other operation and maintenance175,236 169,898 503,242 486,525 
Decommissioning19,567 18,449 57,847 54,596 
Taxes other than income taxes36,892 34,379 96,741 92,611 
Depreciation and amortization90,887 84,515 269,442 252,574 
Other regulatory charges (credits) - net31,988 (28,348)(27,649)(67,632)
TOTAL536,936 426,741 1,440,577 1,224,636 
OPERATING INCOME185,747 217,648 415,766 393,432 
OTHER INCOME
Allowance for equity funds used during construction4,113 3,876 10,714 10,671 
Interest and investment income53,661 2,218 78,809 18,402 
Miscellaneous - net(4,805)(4,465)(15,968)(17,034)
TOTAL52,969 1,629 73,555 12,039 
INTEREST EXPENSE
Interest expense35,452 36,902 104,862 108,494 
Allowance for borrowed funds used during construction(1,793)(1,702)(4,655)(4,686)
TOTAL33,659 35,200 100,207 103,808 
INCOME BEFORE INCOME TAXES205,057 184,077 389,114 301,663 
Income taxes50,166 48,234 84,593 61,055 
NET INCOME$154,891 $135,843 $304,521 $240,608 
See Notes to Financial Statements.


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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$304,521 $240,608 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization380,481 366,549 
Deferred income taxes, investment tax credits, and non-current taxes accrued105,147 79,948 
Changes in assets and liabilities:
Receivables(107,075)(73,890)
Fuel inventory26,521 4,761 
Accounts payable15,485 (26,547)
Taxes accrued(19,899)(10,733)
Interest accrued25,616 18,125 
Deferred fuel costs(113,004)3,203 
Other working capital accounts(26,618)(9,027)
Provisions for estimated losses(1,266)3,508 
Other regulatory assets74,022 (50,262)
Other regulatory liabilities(46,061)(484)
Pension and other postretirement liabilities(81,913)(31,245)
Other assets and liabilities(82,880)(2,562)
Net cash flow provided by operating activities453,077 511,952 
INVESTING ACTIVITIES
Construction expenditures(495,203)(593,249)
Allowance for equity funds used during construction10,714 10,671 
Payment for purchase of assets— (5,988)
Nuclear fuel purchases(72,528)(72,601)
Proceeds from sale of nuclear fuel16,239 30,638 
Proceeds from nuclear decommissioning trust fund sales434,674 254,847 
Investment in nuclear decommissioning trust funds(436,658)(266,397)
Changes in money pool receivable - net(4,191)(51,697)
Changes in securitization account— 4,036 
Litigation proceeds for reimbursement of spent nuclear fuel storage costs— 55,001 
Net cash flow used in investing activities(546,953)(634,739)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt708,126 1,058,977 
Retirement of long-term debt(717,214)(298,071)
Change in money pool payable - net— (21,634)
Common equity distributions paid(25,000)(25,000)
Other33,173 2,900 
Net cash flow provided by (used in) financing activities(915)717,172 
Net increase (decrease) in cash and cash equivalents(94,791)594,385 
Cash and cash equivalents at beginning of period192,128 3,519 
Cash and cash equivalents at end of period$97,337 $597,904 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: 
Cash paid during the period for:
Interest - net of amount capitalized$77,434 $86,906 
See Notes to Financial Statements.
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CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$867 $24,108 
Temporary cash investments96,470 168,020 
Total cash and cash equivalents97,337 192,128 
Accounts receivable:
Customer235,409 183,719 
Allowance for doubtful accounts(18,997)(18,334)
Associated companies52,447 34,216 
Other55,837 35,845 
Accrued unbilled revenues131,016 109,000 
Total accounts receivable455,712 344,446 
Deferred fuel costs59,541 — 
Fuel inventory - at average cost17,290 43,811 
Materials and supplies - at average cost246,719 237,640 
Deferred nuclear refueling outage costs45,525 32,692 
Prepayments and other15,434 13,296 
TOTAL937,558 864,013 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,376,256 1,273,921 
Other338 341 
TOTAL1,376,594 1,274,262 
UTILITY PLANT
Electric13,135,507 12,905,322 
Construction work in progress401,058 234,213 
Nuclear fuel166,440 163,044 
TOTAL UTILITY PLANT13,703,005 13,302,579 
Less - accumulated depreciation and amortization5,449,425 5,255,355 
UTILITY PLANT - NET8,253,580 8,047,224 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets1,758,362 1,832,384 
Deferred fuel costs68,618 68,220 
Other17,513 14,028 
TOTAL1,844,493 1,914,632 
TOTAL ASSETS$12,412,225 $12,100,131 
See Notes to Financial Statements.
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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$— $485,000 
Accounts payable:
Associated companies67,547 59,448 
Other209,269 208,591 
Customer deposits91,575 98,506 
Taxes accrued61,938 81,837 
Interest accrued48,361 22,745 
Deferred fuel costs— 53,065 
Other45,930 40,628 
TOTAL524,620 1,049,820 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued1,406,576 1,286,123 
Accumulated deferred investment tax credits29,599 30,500 
Regulatory liability for income taxes - net441,555 467,031 
Other regulatory liabilities666,287 686,872 
Decommissioning1,372,007 1,314,160 
Accumulated provisions68,903 70,169 
Pension and other postretirement liabilities279,615 361,682 
Long-term debt3,959,194 3,482,507 
Other108,179 75,098 
TOTAL8,331,915 7,774,142 
Commitments and Contingencies
EQUITY
Member's equity3,555,690 3,276,169 
TOTAL3,555,690 3,276,169 
TOTAL LIABILITIES AND EQUITY$12,412,225 $12,100,131 
See Notes to Financial Statements.
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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Member's Equity
(In Thousands)
Balance at December 31, 2019$3,125,937 
Net income44,595 
Balance at March 31, 2020$3,170,532 
Net income60,170 
Balance at June 30, 2020$3,230,702 
Net income135,843 
Common equity distributions(25,000)
Balance at September 30, 2020$3,341,545 
Balance at December 31, 2020$3,276,169 
Net income93,037 
Balance at March 31, 2021$3,369,206 
Net income56,593 
Balance at June 30, 2021$3,425,799 
Net income154,891 
Common equity distributions(25,000)
Balance at September 30, 2021$3,555,690 
See Notes to Financial Statements.
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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Ida

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and transmission systems resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida are currently estimated to be in the range of $2.0 billion to $2.3 billion. Also, Entergy Louisiana’s revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.

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 $800 million and construction work in progress of approximately $1.2 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.

Entergy Louisiana is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of approximately $1 billion of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “Storm Cost Filings - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. Storm cost recovery or financing will be subject to review by applicable regulatory authorities, with a prudence review likely being initiated in the first quarter of 2022.

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of Entergy Louisiana’s service area. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Louisiana’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Louisiana were approximately $285 million in February 2021 compared to approximately $95 million in February 2020. See Note 2 to the financial statements herein for discussion of the storm cost filings made in 2021 by Entergy Louisiana. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Louisiana.

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Results of Operations

Net Income

Third Quarter 2021 Compared to Third Quarter 2020

Net income remained relatively unchanged, increasing by $1 million, primarily due to higher retail electric price, higher other income, and lower other operation and maintenance expenses, partially offset by lower volume/weather, higher depreciation and amortization expenses, and higher interest expense.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income decreased $48.3 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 decrease was higher other operation and maintenance expenses, higher depreciation and amortization expenses, a higher effective income tax rate, and higher interest expense. The decrease was partially offset by higher retail electric price. See Note 3 to the financial statements in the Form 10-K for further discussion of the tax settlement.

Operating Revenues

Third Quarter 2021 Compared to Third Quarter 2020

Following is an analysis of the change in operating revenues comparing the third quarter 2021 to the third quarter 2020:
Amount
(In Millions)
2020 operating revenues$1,120.0 
Fuel, rider, and other revenues that do not significantly affect net income300.3 
Retail electric price37.8 
Volume/weather(37.4)
2021 operating revenues$1,420.7 

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 retail electric price variance is primarily due to:

•an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020;
•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center; and
•an increase in formula rate plan revenues, including increases in the transmission and distribution recovery mechanisms, implemented with the first billing cycle of September 2021.

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

The volume/weather variance is primarily due to the effect of a decrease in the unbilled sales period, partially offset by an increase in billed sales. The decrease in the unbilled sales period was primarily due to a decrease in usage as a result of Hurricane Ida in the third quarter 2021. The increase in billed sales is due to an increase in industrial usage primarily due to increased demand from expansion projects, primarily in the chemicals, metals, and transportation industries, increased demand from existing customers, primarily in the chemicals and industrial gases industries, and an increase in demand from co-generation customers. The increase in billed sales is partially offset by less favorable weather on residential and commercial sales and a decrease in residential and commercial usage primarily due to the effects of Hurricane Ida in the third quarter 2021. The decrease in residential and commercial usage is partially offset by the effects of Hurricane Laura in the third quarter 2020. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the impacts from the storms.

Billed electric energy sales for Entergy Louisiana for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential4,259 4,557 (7)
Commercial2,950 3,033 (3)
Industrial7,687 7,129 8 
Governmental202 202 — 
  Total retail 15,098 14,921 1 
Sales for resale:
  Associated companies1,397 1,477 (5)
  Non-associated companies803 630 27 
Total17,298 17,028 2 

See Note 13 to the financial statements herein for additional discussion of Entergy Louisiana’s operating revenues.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:

Amount
(In Millions)
2020 operating revenues$3,062.3 
Fuel, rider, and other revenues that do not significantly affect net income624.6 
Retail electric price113.2 
Volume/weather(4.2)
2021 operating revenues$3,795.9 

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
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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:

•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;
•an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020;
•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center; and
•an increase in formula rate plan revenues, including increases in the transmission and distribution recovery mechanisms, implemented with the first billing cycle of September 2021.

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

The volume/weather variance is primarily due to a decrease in the unbilled sales period, partially offset by an increase in billed sales. The decrease in the unbilled sales period was primarily due to a decrease in usage in the third quarter 2021 as a result of Hurricane Ida. The increase in billed sales is due to the effect of more favorable weather on residential sales and an increase in industrial usage primarily due to increased demand from expansion projects, primarily in the chemicals and transportation industries, and an increase in demand from co-generation customers. The increase in industrial usage is partially offset by a decrease in demand from mid-to-small customers and existing customers in the chemicals and petroleum refining industries. The increase in billed sales is partially offset by a decrease in residential and commercial usage primarily due to the effects of Hurricane Ida in the third quarter 2021. The decrease in residential and commercial usage is partially offset by the effects of Hurricane Laura in the third quarter 2020. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the impacts from the storms.

Billed electric energy sales for Entergy Louisiana for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential10,728 10,771 — 
Commercial7,860 7,947 (1)
Industrial22,431 22,006 2 
Governmental600 590 2 
  Total retail 41,619 41,314 1 
Sales for resale:
  Associated companies3,523 4,225 (17)
  Non-associated companies1,741 1,631 7 
Total46,883 47,170 (1)

See Note 13 to the financial statements herein for additional discussion of Entergy Louisiana’s operating revenues.

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Other Income Statement Variances

Third Quarter 2021 Compared to Third Quarter 2020

Other operation and maintenance expenses decreased primarily due to a gain of $14.8 million on the sale of a pipeline.

The decrease was partially offset by:

•an increase of $8.2 million in distribution operations expenses primarily due to higher reliability costs and higher vegetation maintenance costs; and
•an increase of $2.6 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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.

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

Other income increased primarily due to changes in decommissioning trust fund activity.

Interest expense increased primarily due to:

•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020; and
•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021.

The increase was partially offset by the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and the repayment of $200 million of 4.8% Series mortgage bonds in May 2021.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $13.7 million in distribution operations expenses primarily due to higher reliability costs and higher vegetation maintenance costs;
•an increase of $11.3 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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;
•an increase of $17.3 million in nuclear generation expenses primarily due to a higher scope of work performed in 2021 as compared to 2020 primarily due to the effects of the COVID-19 pandemic in 2020;
•an increase of $7.5 million in non-nuclear generation expenses due to higher expenses associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020, and the Washington Parish Energy Center, purchased in November 2020;
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•an increase of $5.8 million in energy efficiency costs due to the timing of recovery from customers;
•lower nuclear insurance refunds of $4.2 million;
•an increase of $3.9 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements in the Form 10-K for further information on the recovery of these costs; and
•an increase of $3.5 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives.

The increase was partially offset by a gain of $14.8 million, recorded in the third quarter 2021, on the sale of a pipeline.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes. Ad valorem taxes increased primarily due to higher 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, and the Washington Parish Energy Center, which was placed in service in November 2020.

Other regulatory charges (credits) - net includes 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 3 in the Form 10-K for further discussion of the settlement and savings obligation.

Other income increased primarily due to changes in decommissioning trust fund activity. The increase was partially offset by a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.

Interest expense increased primarily due to:

•the issuance of $350 million of 2.90% Series mortgage bonds in March 2020;
•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;
•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021; and
•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.

The increase was partially offset by the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and $200 million of 4.8% Series mortgage bonds in May 2021.

Income Taxes

The effective income tax rate was 20.1% for the third quarter 2021 and 18.4% for the nine months ended September 30, 2021. The differences in the effective income tax rates for the third quarter 2021 and the nine months ended September 30, 2021 versus the federal statutory rate of 21% were primarily due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests, 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.

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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.

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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Cash and cash equivalents at beginning of period$728,020 $2,006 
Cash flow provided by (used in):
    Operating activities1,047,987 1,113,574 
    Investing activities(2,224,730)(1,096,819)
    Financing activities715,416 233,402 
Net increase (decrease) in cash and cash equivalents(461,327)250,157 
Cash and cash equivalents at end of period$266,693 $252,163 

Operating Activities

Net cash flow provided by operating activities decreased $65.6 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•an increase of approximately $130.7 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Hurricane Ida restoration efforts. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of storm restoration efforts;
•an increase of $29 million in spending on nuclear refueling outages;
•income tax refunds of $20.7 million in 2020. Entergy Louisiana had income tax refunds in 2020 as a result of a refund of an overpayment on a prior year state income tax return; and
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•an increase of $28.4 million in pension contributions in 2021. 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 decrease was partially offset by the timing of collection of receivables from customers and timing of recovery of fuel and purchased power costs.

Investing Activities

Net cash flow used in investing activities increased $1,127.9 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•an increase of $993.4 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Hurricane Ida restoration efforts. See “Hurricane Ida” above and see the “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of storm restoration efforts;
•an increase of $100.5 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Louisiana’s distribution system;
•$39.1 million in net receipts from storm reserve escrow accounts in 2020;
•an increase of $29.9 million in nuclear decommissioning trust fund activity as a result of a lump sum contribution for amounts collected over a 17-month period. See Note 2 in the Form 10-K for a discussion of nuclear decommissioning expense recovery;
•an increase of $21.6 million in transmission construction expenditures primarily due to a higher scope of work on projects performed in 2021 as compared to 2020;
•an increase of $20.8 million as a result of fluctuations in nuclear fuel activity, primarily 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; and
•an increase of $20.1 million in nuclear construction expenditures primarily due to increased spending on various projects in 2021.

The increase was partially offset by:

•a decrease of $56.1 million in non-nuclear generation construction expenditures due to higher spending in 2020 on the Lake Charles Power Station;
•money pool activity;
•the sale of a pipeline for $15 million in 2021; and
•the purchase of a portion of a transmission operating center from Entergy Services for $14.5 million in 2020.

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 $6.6 million for the nine months ended September 30, 2021 compared to increasing by $21.6 million for the nine months ended September 30, 2020. 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 $482 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

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•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021, as compared to the issuances of $350 million of 2.90% Series mortgage bonds and $300 million of 4.20% Series mortgage bonds, each in March 2020;
•the repayment of $250 million of 3.95% Series mortgage bonds in August 2020;
•money pool activity; and
•net long-term borrowings of $44.3 million in 2021 compared to net repayments of long-term borrowings of $37.9 million in 2020 on the nuclear fuel company variable interest entities’ credit facilities.

The increase was partially offset by:

•the repayment of $200 million of 4.80% Series mortgage bonds in May 2021;
•the repayment of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notes in February 2021; and
•an increase of $38.5 million in common equity distributions in 2021 primarily to maintain Entergy Louisiana’s targeted capital structure. In addition, common equity distributions were lower in 2020 due to spending on the Lake Charles Power Station and the purchase of the Washington Parish Energy Center.

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. The increase in the debt to capital ratio for Entergy Louisiana is primarily due to the issuance of $1 billion of mortgage bonds in March 2021.
September 30,
2021		December 31,
2020
Debt to capital55.3 %54.8 %
Effect of excluding securitization bonds0.0 %0.0 %
Debt to capital, excluding securitization bonds (a)55.3 %54.8 %
Effect of subtracting cash(0.6 %)(2.1 %)
Net debt to net capital, excluding securitization bonds (a)54.7 %52.7 %

(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 is developing its capital investment plan for 2022 through 2024 and currently anticipates making $4.1 billion in capital investments during that period, excluding capital spending as a result of Hurricane Ida. The preliminary estimate includes generation projects to modernize, decarbonize, and diversify Entergy Louisiana’s portfolio; investments in River Bend and Waterford 3; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; 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,
 2021		December 31,
2020		September 30,
2020		December 31,
2019
(In Thousands)
$20,061$13,426$21,649($82,826)

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 June 2026.  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, 2021, 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, 2021, $6.8 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 June 2024.  As of September 30, 2021, $53.2 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, 2021, $49.3 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.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

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Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations, and filed a supplemental formula rate plan evaluation report in August 2018. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2017 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objections/reservations pertaining to Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Cuts and Jobs Act and the treatment of accumulated deferred income taxes related to reductions of rate base, specifically how the accumulated deferred income taxes associated with uncertain tax positions have been accounted for, and test year expenses billed from Entergy Services to Entergy Louisiana. The LPSC staff further reserved its rights for future proceedings and to dispute future proposed adjustments to the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations.

As also 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). In February 2021 the LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. The LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between the LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.

2018 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2018 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objection/reservation pertaining to test year expenses billed from Entergy Services to Entergy Louisiana and outstanding issues from the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations.

2019 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its formula rate plan evaluation report for its 2019 calendar year operations. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2019 test year formula rate plan filing. In its letter, the LPSC staff disputes Entergy Louisiana’s exclusion of approximately $251 thousand of interest income allocated from Entergy Operations and Entergy Services to Entergy Louisiana to the extent that there are other adjustments that would move Entergy Louisiana out of the formula rate plan deadband. The LPSC staff reserved the right to further contest the issue in future proceedings. The LPSC staff further reserved outstanding issues from the 2017 and 2018 formula rate plan evaluation reports and withdrew all other remaining objections/reservations.

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Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

2020 Formula Rate Plan Filing

In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes became effective for bills rendered during the first billing cycle of September 2021. Discovery commenced in the proceeding. In August 2021, Entergy Louisiana submitted an update to its evaluation report to account for various changes. Relative to the June 2021 filing, the total formula rate plan revenue increased by $14.2 million to an updated total of $64.9 million. Legacy Entergy Louisiana formula rate plan revenues will increase by $32.8 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $32.1 million. The results of the 2020 test year evaluation report bandwidth calculation were unchanged as there was no change in the earned return on common equity of 8.45%. In September 2021 the LPSC staff filed a letter with a general statement of objections/reservations because it had not completed its review, and indicated it would update the letter once its review was complete. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.

Storm Cost Filings

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

In August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.

In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and
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cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana withdrew $257 million from its funded storm reserves.

In February 2021, two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs, and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incremental outages. As discussed below in “Fuel and purchased power recovery,” Entergy Louisiana recovered the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs, as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. In September 2021, Entergy Louisiana supplemented the application with a request to establish and securitize a $1 billion restricted storm escrow account for Hurricane Ida related restoration costs, subject to a subsequent prudence review. In total, Entergy Louisiana requested authorization for the issuance of system restoration bonds in one or more series in an aggregate principal amount of $3.18 billion, which includes the costs of re-establishing and funding a storm damage escrow account, carrying costs and unamortized debt costs on interim financing, and issuance costs. In October 2021 an updated procedural schedule was established with a hearing in March 2022.

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. In September 2021 the LPSC submitted its audit report and found that all costs recovered through the fuel adjustment clause were reasonable and eligible for recovery through the fuel adjustment clause. The report did contain prospective recommendations on internal informational reporting.

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing.

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Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. Discovery is ongoing, and no audit report has been filed.

COVID-19 Orders

As discussed in the Form 10-K, 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. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana had a regulatory asset of $59.2 million for costs associated with the COVID-19 pandemic.

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, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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 LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$1,407,737 $1,110,217 $3,741,979 $3,024,359 
Natural gas12,971 9,805 53,971 37,962 
TOTAL1,420,708 1,120,022 3,795,950 3,062,321 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale421,464 162,981 922,060 469,083 
Purchased power176,473 160,069 573,030 474,598 
Nuclear refueling outage expenses11,932 13,796 37,407 41,080 
Other operation and maintenance239,132 244,136 752,214 693,010 
Decommissioning17,250 16,407 51,108 48,611 
Taxes other than income taxes63,428 61,797 167,880 160,592 
Depreciation and amortization165,469 154,162 489,343 453,552 
Other regulatory charges (credits) - net(1,920)(17,822)7,560 (25,892)
TOTAL1,093,228 795,526 3,000,602 2,314,634 
OPERATING INCOME327,480 324,496 795,348 747,687 
OTHER INCOME
Allowance for equity funds used during construction7,247 6,255 20,183 27,197 
Interest and investment income39,225 61,487 171,197 135,625 
Miscellaneous - net(8,924)(40,025)(79,595)(57,235)
TOTAL37,548 27,717 111,785 105,587 
INTEREST EXPENSE
Interest expense87,295 82,716 260,731 248,529 
Allowance for borrowed funds used during construction(3,278)(3,256)(9,105)(13,590)
TOTAL84,017 79,460 251,626 234,939 
INCOME BEFORE INCOME TAXES281,011 272,753 655,507 618,335 
Income taxes56,536 49,287 120,479 35,014 
NET INCOME$224,475 $223,466 $535,028 $583,321 
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
Net Income$224,475 $223,466 $535,028 $583,321 
Other comprehensive income (loss)
Pension and other postretirement liabilities (net of tax expense (benefit) of ($46), ($282), $18, and $2,724)
(131)(800)50 7,722 
Other comprehensive income (loss)(131)(800)50 7,722 
Comprehensive Income$224,344 $222,666 $535,078 $591,043 
See Notes to Financial Statements.


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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$535,028 $583,321 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization607,299 591,045 
Deferred income taxes, investment tax credits, and non-current taxes accrued159,723 56,767 
Changes in working capital:
Receivables(91,771)(100,718)
Fuel inventory5,763 (3,845)
Accounts payable450,064 169,577 
Prepaid taxes and taxes accrued94,751 148,379 
Interest accrued4,464 (4,220)
Deferred fuel costs(49,786)(61,732)
Other working capital accounts(41,769)(33,691)
Changes in provisions for estimated losses(764)(42,624)
Changes in other regulatory assets(938,646)(129,843)
Changes in other regulatory liabilities92,138 (19,761)
Changes in pension and other postretirement liabilities(68,132)(49,168)
Other289,625 10,087 
Net cash flow provided by operating activities1,047,987 1,113,574 
INVESTING ACTIVITIES
Construction expenditures(2,147,096)(1,064,765)
Allowance for equity funds used during construction20,183 27,197 
Payment for purchase of assets— (14,511)
Proceeds from sale of assets15,000 — 
Nuclear fuel purchases(75,349)(76,392)
Proceeds from the sale of nuclear fuel13,201 35,041 
Receipts from storm reserve escrow account— 40,601 
Payments to storm reserve escrow account— (1,467)
Changes to securitization account(2,815)(5,925)
Proceeds from nuclear decommissioning trust fund sales505,840 281,131 
Investment in nuclear decommissioning trust funds(555,749)(301,170)
Changes in money pool receivable - net(6,635)(21,649)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs8,690 5,090 
Net cash flow used in investing activities(2,224,730)(1,096,819)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt2,404,102 1,800,392 
Retirement of long-term debt(1,628,383)(1,453,564)
Change in money pool payable - net— (82,826)
Distributions paid:
Common equity distributions paid(60,000)(21,500)
Other(303)(9,100)
Net cash flow provided by financing activities715,416 233,402 
Net increase (decrease) in cash and cash equivalents(461,327)250,157 
Cash and cash equivalents at beginning of period728,020 2,006 
Cash and cash equivalents at end of period$266,693 $252,163 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$247,878 $246,456 
Income taxes$— ($20,684)
See Notes to Financial Statements.
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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$401 $1,303 
Temporary cash investments266,292 726,717 
Total cash and cash equivalents266,693 728,020 
Accounts receivable:
Customer380,218 317,905 
Allowance for doubtful accounts(38,103)(45,693)
Associated companies95,988 81,624 
Other42,341 41,760 
Accrued unbilled revenues192,398 178,840 
Total accounts receivable672,842 574,436 
Deferred fuel costs52,036 2,250 
Fuel inventory44,917 50,680 
Materials and supplies - at average cost463,854 437,933 
Deferred nuclear refueling outage costs50,004 48,407 
Prepayments and other51,239 36,813 
TOTAL1,601,585 1,878,539 
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests1,390,587 1,390,587 
Decommissioning trust funds1,987,336 1,794,042 
Non-utility property - at cost (less accumulated depreciation)332,838 323,110 
Other13,622 13,399 
TOTAL3,724,383 3,521,138 
UTILITY PLANT
Electric26,433,677 25,619,789 
Natural gas277,164 262,744 
Construction work in progress1,908,777 667,281 
Nuclear fuel208,699 210,128 
TOTAL UTILITY PLANT28,828,317 26,759,942 
Less - accumulated depreciation and amortization9,735,089 9,372,224 
UTILITY PLANT - NET19,093,228 17,387,718 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $— as of September 30, 2021 and $5,088 as of December 31, 2020)
2,664,712 1,726,066 
Deferred fuel costs168,122 168,122 
Other39,938 23,924 
TOTAL2,872,772 1,918,112 
TOTAL ASSETS$27,291,968 $24,705,507 
See Notes to Financial Statements.
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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$— $240,000 
Accounts payable:
Associated companies124,691 103,148 
Other2,411,444 1,450,008 
Customer deposits150,826 152,612 
Taxes accrued137,368 42,617 
Interest accrued96,713 92,249 
Current portion of unprotected excess accumulated deferred income taxes33,400 31,138 
Other61,681 62,968 
TOTAL3,016,123 2,174,740 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued2,307,263 2,138,522 
Accumulated deferred investment tax credits103,770 107,317 
Regulatory liability for income taxes - net410,807 447,628 
Other regulatory liabilities1,044,990 918,293 
Decommissioning1,632,846 1,573,307 
Accumulated provisions24,175 24,939 
Pension and other postretirement liabilities624,645 692,728 
Long-term debt (includes securitization bonds of $—as of September 30, 2021 and $10,278 as of December 31, 2020)
9,813,493 8,787,451 
Other381,129 382,894 
TOTAL16,343,118 15,073,079 
Commitments and Contingencies
EQUITY
Member's equity7,928,350 7,453,361 
Accumulated other comprehensive income4,377 4,327 
TOTAL7,932,727 7,457,688 
TOTAL LIABILITIES AND EQUITY$27,291,968 $24,705,507 
See Notes to Financial Statements.
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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Common Equity
Member’s
Equity		Accumulated
Other
Comprehensive
Income		Total
(In Thousands)
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, 2020$6,570,442 $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, 2020$6,735,888 $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 
Balance at December 31, 2020$7,453,361 $4,327 $7,457,688 
Net income166,626 — 166,626 
Other comprehensive loss— (407)(407)
Other(16)— (16)
Balance at March 31, 2021$7,619,971 $3,920 $7,623,891 
Net income143,927 — 143,927 
Other comprehensive income— 588 588 
Other(12)— (12)
Balance at June 30, 2021$7,763,886 $4,508 $7,768,394 
Net income224,475 — 224,475 
Other comprehensive loss— (131)(131)
Distributions declared on common equity(60,000)— (60,000)
Other(11)— (11)
Balance at September 30, 2021$7,928,350 $4,377 $7,932,727 
See Notes to Financial Statements.
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ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Mississippi’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Mississippi were approximately $65 million in February 2021 compared to approximately $35 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of storm cost recovery and fuel cost recovery at Entergy Mississippi.

In February 2021 the MPSC announced that it would launch a comprehensive review of the condition and resiliency of the state’s public utility infrastructure in response to the impacts of the February 2021 winter storms. Although the MPSC did not open a formal docket, the MPSC submitted data requests to Entergy Mississippi regarding the actions taken to ensure reliable operations of the electric network during the winter storm events and in anticipation of other future extreme weather events. In April 2021, Entergy Mississippi submitted responses to the MPSC data requests.

In April 2021 the MPSC opened a proceeding to investigate Entergy Mississippi’s membership in MISO. In the order, the MPSC noted the impact of the February 2021 winter storms, stating that it observed “excessive prices of natural gas and electricity” during the winter event. Entergy Mississippi submitted comments in the proceeding in June 2021. In October 2021 the MPSC established a procedural schedule requesting additional comments and responses.

Results of Operations

Net Income

Third Quarter 2021 Compared to Third Quarter 2020

Net income increased $4 million primarily due to higher retail electric price and lower other operation and maintenance expenses, partially offset by higher depreciation and amortization expenses and lower volume/weather.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income increased $20 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher depreciation and amortization expenses, higher other operation and maintenance expenses, higher taxes other than income taxes, higher interest expenses, and a higher effective tax rate.

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Management's Financial Discussion and Analysis
Operating Revenues

Third Quarter 2021 Compared to Third Quarter 2020

Following is an analysis of the change in operating revenues comparing the third quarter 2021 to the third quarter 2020:
Amount
(In Millions)
2020 operating revenues$356.5 
Fuel, rider, and other revenues that do not significantly affect net income43.1 
Retail electric price24.2 
Volume/weather(3.5)
2021 operating revenues$420.3 

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 retail electric price variance is primarily due to increases in formula rate plan rates effective with the first billing cycles of April 2021 and July 2021. See Note 2 to the financial statements herein for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to a decrease in usage during the unbilled sales period.

Billed electric energy sales for Entergy Mississippi for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential1,799 1,855 (3)
Commercial1,337 1,298 3 
Industrial615 629 (2)
Governmental117 115 2 
  Total retail 3,868 3,897 (1)
Sales for resale:
  Non-associated companies1,134 1,762 (36)
Total5,002 5,659 (12)

See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.
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Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:
Amount
(In Millions)
2020 operating revenues$948.4 
Fuel, rider, and other revenues that do not significantly affect net income100.1 
Retail electric price49.0 
Volume/weather8.5 
2021 operating revenues$1,106 

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 retail electric price variance is primarily due to increases in formula rate plan rates effective with the first billing cycles of April 2020, April 2021, and July 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings.

The volume/weather variance is primarily due an increase of 257 GWh, or 3%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in commercial usage partially offset by a decrease in industrial usage and a decrease in usage during the unbilled sales period. The increase in commercial usage was primarily due to an increase in customers and reduced impacts from the COVID-19 pandemic on businesses as compared to prior year. The decrease in industrial usage is primarily due to a decrease in demand from mid-to-small customers.

Billed electric energy sales for Entergy Mississippi for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential4,389 4,222 4 
Commercial3,387 3,270 4 
Industrial1,710 1,747 (2)
Governmental309 299 3 
  Total retail 9,795 9,538 3 
Sales for resale:
  Non-associated companies4,230 3,628 17 
Total14,025 13,166 7 

See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.

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Other Income Statement Variances

Third Quarter 2021 Compared to Third Quarter 2020

Other operation and maintenance expenses decreased primarily due to a decrease of $3.7 million in energy efficiency expenses due to the timing of recovery from customers and a decrease of $1.5 million in vegetation maintenance costs. The decrease was partially offset by an increase of $1.4 million as a result of the amount of transmission costs allocated by MISO.

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

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $8.2 million in distribution operations expenses primarily due to higher vegetation maintenance costs, higher contractor costs, and higher reliability costs;
•an increase of $3.9 million as a result of the amount of transmission costs allocated by MISO;
•an increase of $2.5 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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;
•an increase of $1.3 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives;
•an increase of $1.2 million primarily due to the amortization of deferred litigation costs related to the Mississippi Attorney General complaint against Entergy Mississippi, which was dismissed by the Hinds County Chancery Court in February 2020; and
•several individually insignificant items.

The increase was partially offset by a decrease of $6.7 million in energy efficiency expenses due to the timing of recovery from customers, a decrease of $2.3 million in loss provisions, and a decrease of $1.8 million in meter reading expenses as a result of the deployment of advanced metering systems.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes due to higher assessments.

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

Other regulatory charges (credits) - net includes regulatory credits of $19.9 million, recorded in the second quarter 2021, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.

Interest expense increased primarily due to the issuance of $170 million of 3.50% Series mortgage bonds in May 2020 and an additional $200 million in a reopening of the same series in March 2021.

Income Taxes

The effective income tax rate was 22.9% for the third quarter 2021 and 22.4% for the nine months ended September 30, 2021. The differences in the effective income tax rates for the third quarter 2021 and the nine
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months ended September 30, 2021 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 and book and tax differences related to the allowance for equity funds used during construction.

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 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Cash and cash equivalents at beginning of period$18 $51,601 
Cash flow provided by (used in):
Operating activities249,768 200,273 
Investing activities(468,198)(374,978)
Financing activities218,440 166,142 
Net increase (decrease) in cash and cash equivalents10 (8,563)
Cash and cash equivalents at end of period$28 $43,038 

Operating Activities

Net cash flow provided by operating activities increased $49.5 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to the timing of collections of receivables from customers. The increase was partially offset by increased fuel costs, including those related to Winter Storm Uri, the timing of payments to vendors, and an increase of approximately $13.3 million in storm spending in 2021, primarily due to Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements in the Form 10-K for a discussion of fuel and purchased power cost recovery.

Investing Activities

Net cash flow used in investing activities increased $93.2 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•an increase of $94.5 million in distribution construction expenditures primarily due to increased spending on the reliability and infrastructure of Entergy Mississippi’s distribution system and storm spending in 2021; and
•money pool activity.
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The increase was partially offset by $24.6 million in plant upgrades for Choctaw Generating Station in March 2020.

Decreases in Entergy Mississippi’s receivable from the money pool are a source of cash flow, and Entergy Mississippi’s receivable from the money pool decreased by $41 million for the nine months ended September 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility’s subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $52.3 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to the issuance of $200 million of 3.50% Series mortgage bonds in March 2021 and money pool activity, partially offset by the issuance of $170 million of 3.50% Series mortgage bonds in May 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.

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow and Entergy Mississippi’s payable to the money pool increased $18.1 million for the nine months ended September 30, 2021.

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 $200 million of mortgage bonds in March 2021.
September 30,
 2021		December 31,
2020
Debt to capital52.3 %51.7 %
Effect of subtracting cash— %— %
Net debt to net capital52.3 %51.7 %

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.

Entergy Mississippi is developing its capital investment plan for 2022 through 2024 and currently anticipates making $1.5 billion in capital investments during that period. The preliminary estimate includes generation projects to modernize, decarbonize, and diversify Entergy Mississippi’s portfolio, such as the Sunflower Solar Facility; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; 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,
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business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:
September 30,
 2021		December 31,
2020		September 30,
 2020		December 31,
2019
(In Thousands)
($34,603)($16,516)$3,721$44,693

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 2022. No borrowings were outstanding under the credit facilities as of September 30, 2021.  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, 2021, $2.3 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 $33.2 million in its storm reserve escrow account at September 30, 2021.

Sunflower Solar Facility

As discussed in the Form 10-K, in November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW 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 project is being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. 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 to recover the non-fuel related costs of additional owned capacity owned by Entergy Mississippi, including the annual ownership costs of the Sunflower Solar Facility. Recovery through the interim capacity rate adjustment requires MPSC approval for each new resource. 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 second quarter 2022.

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.

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base,
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within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of September 30, 2021, Entergy Mississippi had a regulatory asset of $18.2 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.

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Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

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

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, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$420,319 $356,496 $1,105,978 $948,372 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale54,505 41,771 180,315 143,798 
Purchased power85,247 68,296 217,730 177,618 
Other operation and maintenance72,523 74,891 214,253 203,571 
Taxes other than income taxes25,911 24,638 78,886 74,525 
Depreciation and amortization57,130 52,486 168,324 155,937 
Other regulatory charges (credits) - net25,810 571 12,309 (9,806)
TOTAL321,126 262,653 871,817 745,643 
OPERATING INCOME99,193 93,843 234,161 202,729 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction2,006 1,793 5,703 4,820 
Interest and investment income1 13 50 268 
Miscellaneous - net(1,844)(2,497)(6,362)(7,382)
TOTAL163 (691)(609)(2,294)
INTEREST EXPENSE
Interest expense19,024 17,650 55,559 51,425 
Allowance for borrowed funds used during construction(849)(773)(2,378)(1,958)
TOTAL18,175 16,877 53,181 49,467 
INCOME BEFORE INCOME TAXES81,181 76,275 180,371 150,968 
Income taxes18,586 17,686 40,388 30,960 
NET INCOME $62,595 $58,589 $139,983 $120,008 
See Notes to Financial Statements.


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STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$139,983 $120,008 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization168,324 155,937 
Deferred income taxes, investment tax credits, and non-current taxes accrued53,629 34,848 
Changes in assets and liabilities:
Receivables(36,754)(21,376)
Fuel inventory5,564 (359)
Accounts payable48,413 5,863 
Taxes accrued(30,881)(10,366)
Interest accrued4,632 9,075 
Deferred fuel costs(95,310)(45,998)
Other working capital accounts(40,911)(7,372)
Provisions for estimated losses(8,087)(28)
Other regulatory assets(15,366)(31,987)
Other regulatory liabilities49,036 (10,592)
Pension and other postretirement liabilities(17,454)(11,451)
Other assets and liabilities24,950 14,071 
Net cash flow provided by operating activities249,768 200,273 
INVESTING ACTIVITIES
Construction expenditures(473,956)(393,887)
Allowance for equity funds used during construction5,703 4,820 
Change in money pool receivable - net— 40,972 
Payment for the purchase of plant or assets— (28,612)
Other55 1,729 
Net cash flow used in investing activities(468,198)(374,978)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt200,539 165,399 
Change in money pool payable - net18,087 — 
Common equity distributions paid— (7,500)
Other(186)8,243 
Net cash flow provided by financing activities218,440 166,142 
Net increase (decrease) in cash and cash equivalents10 (8,563)
Cash and cash equivalents at beginning of period18 51,601 
Cash and cash equivalents at end of period$28 $43,038 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$49,080 $40,551 
Income taxes($8,045)$— 
See Notes to Financial Statements.
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BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
 20212020
 (In Thousands)
CURRENT ASSETS  
Cash and cash equivalents:  
Cash$26 $11 
Temporary cash investments2 7 
Total cash and cash equivalents28 18 
Accounts receivable:  
Customer115,831 105,732 
Allowance for doubtful accounts(11,350)(19,527)
Associated companies12,111 2,740 
Other13,689 11,821 
Accrued unbilled revenues66,753 59,514 
Total accounts receivable197,034 160,280 
Deferred fuel costs80,619 — 
Fuel inventory - at average cost11,553 17,117 
Materials and supplies - at average cost72,082 59,542 
Prepayments and other28,940 4,876 
TOTAL390,256 241,833 
OTHER PROPERTY AND INVESTMENTS  
Non-utility property - at cost (less accumulated depreciation)4,531 4,543 
Escrow accounts48,884 64,635 
TOTAL53,415 69,178 
UTILITY PLANT  
Electric6,377,803 6,084,730 
Construction work in progress202,495 134,854 
TOTAL UTILITY PLANT6,580,298 6,219,584 
Less - accumulated depreciation and amortization2,102,072 2,005,087 
UTILITY PLANT - NET4,478,226 4,214,497 
DEFERRED DEBITS AND OTHER ASSETS  
Regulatory assets:  
Other regulatory assets482,707 467,341 
Other17,927 14,413 
TOTAL500,634 481,754 
TOTAL ASSETS$5,422,531 $5,007,262 
See Notes to Financial Statements.  
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BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
 20212020
 (In Thousands)
CURRENT LIABILITIES  
Accounts payable:  
Associated companies$80,597 $61,727 
Other148,077 117,629 
Customer deposits85,997 86,200 
Taxes accrued77,203 108,084 
Interest accrued25,521 20,889 
Deferred fuel costs— 14,691 
Other22,591 34,270 
TOTAL439,986 443,490 
NON-CURRENT LIABILITIES  
Accumulated deferred income taxes and taxes accrued704,405 646,674 
Accumulated deferred investment tax credits10,969 9,062 
Regulatory liability for income taxes - net216,620 224,000 
Other regulatory liabilities72,244 15,828 
Asset retirement cost liabilities10,174 9,762 
Accumulated provisions38,417 46,504 
Pension and other postretirement liabilities93,275 110,901 
Long-term debt1,981,945 1,780,577 
Other41,779 47,730 
TOTAL3,169,828 2,891,038 
Commitments and Contingencies  
EQUITY  
Member's equity1,812,717 1,672,734 
TOTAL1,812,717 1,672,734 
TOTAL LIABILITIES AND EQUITY$5,422,531 $5,007,262 
See Notes to Financial Statements.  
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STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
  
 Member's Equity
 (In Thousands)
Balance at December 31, 2019$1,542,151 
Net income22,526 
Common equity distributions(2,500)
Balance at March 31, 2020$1,562,177 
Net income38,893 
Balance at June 30, 2020$1,601,070 
Net income58,589 
Common equity distributions(5,000)
Balance at September 30, 2020$1,654,659 
Balance at December 31, 2020$1,672,734 
Net income25,972 
Balance at March 31, 2021$1,698,706 
Net income51,416 
Balance at June 30, 2021$1,750,122 
Net income62,595 
Balance at September 30, 2021$1,812,717 
See Notes to Financial Statements.
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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Ida

In August 2021, Hurricane Ida caused significant damage to Entergy New Orleans’s service area, including Entergy’s electrical grid. The storm resulted in widespread power outages, including the loss of 100% of Entergy New Orleans’s load, and significant damage to distribution and transmission infrastructure, including the loss of connectivity to the eastern interconnection. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida are currently estimated to be in the range of $120 million to $150 million. Also, Entergy New Orleans’s revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.

Entergy New Orleans has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy New Orleans recorded corresponding regulatory assets of approximately $45 million and construction work in progress of approximately $75 million. Entergy New Orleans 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.

Entergy New Orleans is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Entergy New Orleans believes its liquidity is sufficient to meet its current obligations. As of September 30, 2021, Entergy New Orleans has $26.4 million of cash and cash equivalents and the ability to borrow up to $150 million from the Entergy System money pool.

In September 2021 the City Council issued a number of resolutions associated with Hurricane Ida including: (1) a resolution initiating an investigation of Entergy New Orleans’s preparation for and response to Hurricane Ida and a statement that the City Council opposes recovery of Hurricane Ida costs unless it is demonstrated that any such restoration costs are unrelated to deficient maintenance practices; and (2) resolutions requesting that the LPSC and the FERC study the prudence of Entergy Louisiana’s transmission planning. Entergy New Orleans will oppose any attempt by the City Council to alter the legal standard in Louisiana that allows Entergy New Orleans to recover its prudently incurred hurricane restoration costs. Because storm cost recovery or financing will be subject to review by applicable regulatory authorities and Entergy New Orleans has not gone through the regulatory process regarding Hurricane Ida 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 and incremental losses it may ultimately recover, or the timing of such recovery.

Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Zeta, which caused significant damage to Entergy New Orleans’s service area. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. See Note 2 to the financial statements herein for discussion of the storm cost certification filing made in 2021 by Entergy New Orleans.
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Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy New Orleans’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy New Orleans were approximately $35 million in February 2021 compared to approximately $25 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of fuel cost recovery at Entergy New Orleans. See “Load Shed Investigation” below for discussion of the investigation initiated by the City Council in February 2021.

Results of Operations

Net Income

Third Quarter 2021 Compared to Third Quarter 2020

Net income decreased $3.5 million primarily due to lower volume/weather and higher depreciation and amortization expenses, partially offset by higher retail electric price.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income decreased $13.2 million primarily due to higher other operation and maintenance expenses, higher depreciation and amortization expenses, lower volume/weather, lower other income, and a higher effective income tax rate. The decrease was partially offset by higher retail electric price.

Operating Revenues

Third Quarter 2021 Compared to Third Quarter 2020

Following is an analysis of the change in operating revenues comparing third quarter 2021 to third quarter 2020:
Amount
(In Millions)
2020 operating revenues$182.1 
Fuel, rider, and other revenues that do not significantly affect net income29.0 
Retail electric price11.6 
Volume/weather(11.5)
2021 operating revenues$211.2 

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 an interim increase in formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case resolution.

The volume/weather variance is primarily due to a decrease of 85 GWh, or 5%, in billed electricity usage,
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primarily due to decreased residential usage resulting from the effect of Hurricane Ida in the third quarter 2021 and the effect of less favorable weather on residential and commercial sales. See “Hurricane Ida” above for further discussion of the effects of Hurricane Ida.

Billed electric energy sales for Entergy New Orleans for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential699 773 (10)
Commercial554 564 (2)
Industrial118 120 (2)
Governmental212 211 — 
  Total retail 1,583 1,668 (5)
Sales for resale:
  Non-associated companies653 588 11 
Total2,236 2,256 (1)

See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:
Amount
(In Millions)
2020 operating revenues$478.7 
Fuel, rider, and other revenues that do not significantly affect net income54.5 
Retail electric price31.2 
Volume/weather(5.1)
2021 operating revenues$559.3 

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 an interim increase in formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case resolution.

The volume/weather variance is primarily due to a decrease of 31 GWh, or 1%, in billed electricity usage primarily due to decreased usage in the residential and industrial sectors, including the effect of Hurricane Ida in the third quarter 2021, partially offset by the effect of more favorable weather on residential sales. See “Hurricane Ida” above for further discussion of the effects of Hurricane Ida.

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Billed electric energy sales for Entergy New Orleans for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential1,786 1,794 — 
Commercial1,487 1,500 (1)
Industrial317 328 (3)
Governmental573 572 — 
  Total retail 4,163 4,194 (1)
Sales for resale:
  Non-associated companies1,271 1,662 (24)
Total5,434 5,856 (7)

See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.

Other Income Statement Variances

Third Quarter 2021 Compared to Third Quarter 2020

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

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $6.2 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages in 2021 as compared to the same period in 2020 and the New Orleans Power Station, which was placed in service in May 2020;
•an increase of $5.6 million in energy efficiency expenses due to the timing of recovery from customers;
•an increase of $2.5 million in distribution operations expenses primarily due to higher vegetation maintenance costs and higher distribution reliability costs; and
•several individually insignificant items.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the New Orleans Power Station, which was placed in service in May 2020.

Other regulatory charges (credits) - net includes regulatory credits recorded in 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 in the Form 10-K for discussion of the rate case resolution.

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 2020, including the New Orleans Power Station project.

Income Taxes

The effective income tax rate was 26% for third quarter 2021 and 27.1% for the nine months ended September 30, 2021. The difference in the effective income tax rates for third quarter 2021 and the nine months
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ended September 30, 2021 versus the federal statutory rate of 21% were 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.

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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Cash and cash equivalents at beginning of period$26 $6,017 
Cash flow provided by (used in):
Operating activities77,450 46,097 
Investing activities(59,423)(169,565)
Financing activities8,335 117,483 
Net increase (decrease) in cash and cash equivalents26,362 (5,985)
Cash and cash equivalents at end of period$26,388 $32 

Operating Activities

Net cash flow provided by operating activities increased $31.4 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to the timing of payments to vendors and the timing of recovery of fuel and purchased power costs. The increase was partially offset by the timing of receivables from customers and an increase of $7.3 million in storm spending in 2021, primarily due to Hurricane Zeta and Hurricane Ida restoration efforts. See “Hurricane Zeta” and “Hurricane Ida” above for discussion of hurricane restoration efforts.

Investing Activities

Net cash flows used in investing activities decreased $110.1 million for the nine months ended
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September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•$83 million in receipts from storm reserve escrow accounts in 2021;
•a decrease of $48.3 million in non-nuclear generation construction expenditures primarily due to lower spending in 2021 on the New Orleans Power Station and the New Orleans Solar Station projects; and
•a decrease of $18.1 million in distribution construction expenditures primarily due to lower spending in 2021 on advanced metering infrastructure.

The decrease in distribution construction expenditures was partially offset by an increase of $29.2 million in storm spending in 2021. See “Hurricane Zeta” and “Hurricane Ida” above for discussion of hurricane restoration efforts.

Financing Activities

Net cash flow provided by financing activities decreased $109.1 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 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, and money pool activity. The decrease was partially offset by long-term credit borrowings of $25 million in 2021 compared to repayments of long-term credit borrowings of $20 million in 2020.

Decreases in Entergy New Orleans’s payable to the money pool are a use of cash flow, and Entergy New Orleans’s payable to the money pool decreased $10.2 million for the nine months ended September 30, 2021 compared to increasing by $5.1 million for the nine months ended September 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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.
September 30,
2021		December 31,
2020
Debt to capital51.4 %51.5 %
Effect of excluding securitization bonds (1.4 %)(1.6 %)
Debt to capital, excluding securitization bonds (a)50.0 %49.9 %
Effect of subtracting cash(1.0 %)— %
Net debt to net capital, excluding securitization bonds (a)49.0 %49.9 %

(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 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
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net debt indicates Entergy New Orleans’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.  

Entergy New Orleans is developing its capital investment plan for 2022 through 2024 and currently anticipates making $510 million in capital investments during that period, excluding capital spending as a result of Hurricane Ida. The preliminary estimate includes generation projects to modernize, decarbonize, and diversify Entergy New Orleans’s portfolio; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; 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,
2021		December 31,
2020		September 30,
2020		December 31,
2019
(In Thousands)
$1,995($10,190)($5,089)$5,191

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 June 2024. 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, 2021, $25 million in cash borrowings and no letters of credit were 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, 2021, 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.

Renewables

As discussed in the Form 10-K, in July 2019, the City Council approved the stipulated settlement related to Entergy New Orleans’s application for three utility-scale solar projects totaling 90 MW. Commercial operation of the 20 MW New Orleans Solar Station commenced in December 2020. Due to a delay resulting from Hurricane Ida, Entergy New Orleans now expects to begin receiving power under the 50 MW Iris Solar and the 20 MW St. James Solar power purchase agreements in 2022.

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.

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Retail Rates

2021 Formula Rate Plan Filing

In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans sought approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula resulted in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also sought to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing was subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. In October 2021 the City Council’s advisors filed a 75-day report recommending a reduction of $10 million for electric revenues and a reduction of $4.5 million for gas revenues, along with one-time credits funded by certain electric regulatory liabilities currently held by Entergy New Orleans for customers. Other parties filed reports arguing that no rate should be implemented until the completion of a management audit of Entergy New Orleans. On October 26, 2021, Entergy New Orleans provided notice to the City Council that it intends to implement rates effective with the first billing cycle of November 2021, with such rates reflecting an amount agreed-upon by Entergy New Orleans including adjustments filed in the City Council’s 75-day report, per the approved process for formula rate plan implementation. The total formula rate plan increase implemented will be $49.5 million, with an increase of $34.9 million in electric revenues and $14.6 million in gas revenues. Also, credits of $17.4 million funded by certain regulatory liabilities currently held by Entergy New Orleans for customers will be issued over a five-month period from November 2021 through March 2022. Resulting rates went into effect with the first billing cycle of November 2021 pursuant to the formula rate plan tariff.

COVID-19 Orders

As discussed in the Form 10-K, 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 and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program was effective from July 1, 2020 through December 31, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. Credits of $4.3 million were applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of September 30, 2021, Entergy New Orleans had a regulatory asset of $12.7 million for costs associated with the COVID-19 pandemic.

Storm Cost Filings

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. In May 2021, Entergy New Orleans filed an application with the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs,
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were reasonable and necessary to enable Entergy New Orleans to restore electric service to its customers and Entergy New Orleans’s electric utility infrastructure. Additionally, Entergy New Orleans plans to make a separate filing at an appropriate time to the City Council requesting replenishment of its storm reserves.

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. The rulemaking considered, among other issues, whether to adopt a renewable portfolio standard, whether such standard should be voluntary or mandatory, what kinds of technologies should qualify for inclusion in the rules, what level, if any, of renewable generation should be required, and whether penalties are an appropriate component of the proposed rules. 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. In February 2021 the City Council amended the proposed draft rules to exclude beneficial electrification and carbon capture from the technologies eligible for credit under the Renewable and Clean Portfolio Standard and opened a 30-day comment period regarding the proposed amendments. Under the rule, however, these technologies can be approved by the City Council as a “qualified measure” on a case-by-case basis. The City Council approved the draft rule, as amended, in May 2021.

Load Shed Investigation

On February 16, 2021, due to high customer demand and limited generation, MISO issued an order requiring load-serving entities throughout its southern region to shed load to protect the integrity of the bulk electric system. Entergy New Orleans was required to shed load of at least 26 MW, but due to certain complications with its automated load shed program and certain load measurement issues, it inadvertently shed approximately 105 MW of load in its service area. The maximum time any customer was without power due to the load shed event was one hour and forty minutes. In late February 2021 the City Council ordered its advisors to conduct an investigation into the load shed event and to issue a report, which was completed and filed in April 2021. The report recommended that the City Council open an additional docket to determine whether any of Entergy New Orleans’s actions were imprudent. In May 2021 the City Council opened a docket directing its advisors to conduct a prudence investigation and determine whether financial and/or other penalties should be imposed by the City Council. In June 2021, Entergy New Orleans filed a response to the show cause docket that outlined how its response to Winter Storm Uri was reasonable under the circumstances. In November 2021 the City Council’s Advisors issued a report that criticized Entergy’s response to the winter storm, including the inadvertent shedding of 105MW of load and communications with customers. The Advisors’ Report, however, did not find that Entergy New Orleans was imprudent and did not recommend a fine under the circumstances. A City Council decision is expected in the first quarter 2022 based on the procedural schedule in the show cause docket. Entergy New Orleans would oppose any attempt to levy a fine under the circumstances presented.

Management Audit

In September 2021 the City Council issued a resolution initiating a management audit of Entergy New Orleans that has been proposed by certain solar advocates. The advocates have proposed a broad scope audit including, but not limited to, ensuring the corporate culture embraces climate solutions, employee salaries, expenses, and capital spending, but the City Council has not yet determined the full scope of the proposed audit. In September 2021 the City Council passed a resolution directing its staff to issue a request for qualifications for firms interested in conducting the audit.

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Utility Alternative Investigation

In September 2021 the City Council issued a resolution directing its staff to initiate a request for qualifications for a third-party firm to study alternatives to Entergy New Orleans as the electric service provider for New Orleans. Entergy responded to the City Council and issued a press release stating that it stands ready to work with the City Council to quickly implement any action taken by the City Council in response to the study. In the press release, Entergy proposed four preliminary options for consideration by the City Council: merger of Entergy New Orleans with Entergy Louisiana, sale of Entergy New Orleans, spinoff of Entergy New Orleans to establish a standalone company, or municipalization of the assets of Entergy New Orleans by the City of New Orleans.

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.

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, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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 NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$192,946 $169,512 $491,855 $427,842 
Natural gas18,283 12,552 67,449 50,867 
TOTAL211,229 182,064 559,304 478,709 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale34,940 15,051 88,462 59,382 
Purchased power75,360 66,868 201,207 181,320 
Other operation and maintenance34,483 34,872 113,638 94,702 
Taxes other than income taxes15,530 15,455 40,380 44,303 
Depreciation and amortization18,444 16,134 54,758 46,835 
Other regulatory charges (credits) - net4,126 1,362 9,831 152 
TOTAL182,883 149,742 508,276 426,694 
OPERATING INCOME28,346 32,322 51,028 52,015 
OTHER INCOME
Allowance for equity funds used during construction433 910 1,067 5,443 
Interest and investment income18 13 32 109 
Miscellaneous - net(205)(600)(711)(1,170)
TOTAL246 323 388 4,382 
INTEREST EXPENSE
Interest expense7,158 7,529 21,149 21,804 
Allowance for borrowed funds used during construction(192)(438)(475)(2,618)
TOTAL6,966 7,091 20,674 19,186 
INCOME BEFORE INCOME TAXES21,626 25,554 30,742 37,211 
Income taxes5,631 6,104 8,345 1,646 
NET INCOME$15,995 $19,450 $22,397 $35,565 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$22,397 $35,565 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization54,758 46,835 
Deferred income taxes, investment tax credits, and non-current taxes accrued11,261 10,382 
Changes in assets and liabilities:
Receivables(24,959)(10,892)
Fuel inventory79 190 
Accounts payable22,863 1,841 
Taxes accrued(1,699)(2,283)
Interest accrued(2,796)(335)
Deferred fuel costs4,280 (5,629)
Other working capital accounts(7,025)(14,122)
Provisions for estimated losses(62,293)1,356 
Other regulatory assets18,412 2,196 
Other regulatory liabilities11,757 (13,389)
Pension and other postretirement liabilities(11,220)(10,373)
Other assets and liabilities41,635 4,755 
Net cash flow provided by operating activities77,450 46,097 
INVESTING ACTIVITIES
Construction expenditures(139,153)(174,011)
Allowance for equity funds used during construction1,067 5,443 
Payment for purchase of assets— (1,584)
Changes in money pool receivable - net(1,995)5,191 
Receipts from storm reserve escrow account83,045 — 
Payments to storm reserve escrow account(7)(428)
Changes in securitization account(2,380)(4,176)
Net cash flow used in investing activities(59,423)(169,565)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt— 138,930 
Retirement of long-term debt19,251 (25,616)
Changes in money pool payable - net(10,190)5,089 
Other(726)(920)
Net cash flow provided by financing activities8,335 117,483 
Net increase (decrease) in cash and cash equivalents26,362 (5,985)
Cash and cash equivalents at beginning of period26 6,017 
Cash and cash equivalents at end of period$26,388 $32 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$23,015 $21,203 
Income taxes$324 $3,332 
See Notes to Financial Statements.
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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$26 $26 
Temporary cash investments26,362 — 
Total cash and cash equivalents26,388 26 
Securitization recovery trust account5,744 3,364 
Accounts receivable: 
Customer96,185 70,694 
Allowance for doubtful accounts(18,625)(17,430)
Associated companies4,288 2,381 
Other10,457 4,248 
Accrued unbilled revenues25,611 31,069 
Total accounts receivable117,916 90,962 
Deferred fuel costs— 2,130 
Fuel inventory - at average cost1,899 1,978 
Materials and supplies - at average cost16,392 16,550 
Prepayments and other11,438 3,715 
TOTAL179,777 118,725 
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)1,016 1,016 
Storm reserve escrow account— 83,038 
TOTAL1,016 84,054 
UTILITY PLANT
Electric1,834,801 1,821,638 
Natural gas365,544 348,024 
Construction work in progress108,818 12,460 
TOTAL UTILITY PLANT2,309,163 2,182,122 
Less - accumulated depreciation and amortization764,178 740,796 
UTILITY PLANT - NET1,544,985 1,441,326 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs4,080 4,080 
Other regulatory assets (includes securitization property of $27,995 as of September 30, 2021 and $35,559 as of December 31, 2020)
248,378 266,790 
Other37,254 23,931 
TOTAL289,712 294,801 
TOTAL ASSETS$2,015,490 $1,938,906 
See Notes to Financial Statements.
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CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$70,000 $— 
Payable due to associated company1,618 1,618 
Accounts payable:
Associated companies51,071 54,234 
Other137,011 60,766 
Customer deposits27,933 27,912 
Taxes accrued3,001 4,700 
Interest accrued5,299 8,095 
Deferred fuel costs2,150 — 
Current portion of unprotected excess accumulated deferred income taxes3,177 3,296 
Other6,094 5,462 
TOTAL307,354 166,083 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued351,119 338,714 
Accumulated deferred investment tax credits16,053 16,095 
Regulatory liability for income taxes - net53,688 55,675 
Asset retirement cost liabilities3,964 3,768 
Accumulated provisions27,605 89,898 
Long-term debt (includes securitization bonds of $35,724 as of September 30, 2021 and $41,291 as of December 31, 2020)
579,550 629,704 
Long-term payable due to associated company10,911 10,911 
Other35,932 21,141 
TOTAL1,078,822 1,165,906 
Commitments and Contingencies
EQUITY
Member's equity629,314 606,917 
TOTAL629,314 606,917 
TOTAL LIABILITIES AND EQUITY$2,015,490 $1,938,906 
See Notes to Financial Statements.
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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
  
 Member's Equity
 (In Thousands)
Balance at December 31, 2019$497,579 
Net income11,186 
Balance at March 31, 2020$508,765 
Net income4,929 
Balance at June 30, 2020$513,694 
Net income19,450 
Balance at September 30, 2020$533,144 
Balance at December 31, 2020$606,917 
Net income1,771 
Balance at March 31, 2021$608,688 
Net income4,631 
Balance at June 30, 2021$613,319 
Net income15,995 
Balance at September 30, 2021$629,314 
See Notes to Financial Statements. 

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Laura and Hurricane Delta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura and Hurricane Delta” in the Form 10-K for a discussion of Hurricane Laura and Hurricane Delta, which caused significant damage to portions of Entergy Texas’s service territory. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Texas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Texas were approximately $185 million in February 2021 compared to approximately $50 million in February 2020. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Texas.

Results of Operations

Net Income

Third Quarter 2021 Compared to Third Quarter 2020

Net income increased $2.7 million primarily due to higher retail electric price and higher volume/weather. The increase was partially offset by higher taxes other than income taxes, lower other income, higher depreciation and amortization expenses, and higher other operation and maintenance expenses.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income increased $18 million primarily due to higher retail electric price and higher volume/weather. The increase was partially offset by lower other income, higher depreciation and amortization expenses, higher other operation and maintenance expenses, higher taxes other than income taxes, and a higher effective income tax rate.

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Operating Revenues

Third Quarter 2021 Compared to Third Quarter 2020

Following is an analysis of the change in operating revenues comparing the third quarter 2021 to the third quarter 2020:
Amount
(In Millions)
2020 operating revenues$494.9 
Fuel, rider, and other revenues that do not significantly affect net income0.3 
Retail electric price41.6 
Volume/weather4.8 
2021 operating revenues$541.6 

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 retail electric price variance is primarily due to the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and increases in the distribution cost recovery factor rider effective October 2020 and March 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.

The volume/weather variance is primarily due to an increase in usage during the unbilled sales period and an increase of 287 GWh, or 5%, in billed electricity usage, including an increase in industrial usage partially offset by the effect of less favorable weather on residential sales. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from mid-to-small and cogeneration customers.

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Billed electric energy sales for Entergy Texas for the three months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential2,019 2,070 (2)
Commercial1,290 1,276 1 
Industrial2,388 2,060 16 
Governmental65 69 (6)
  Total retail 5,762 5,475 5 
Sales for resale:
  Associated companies324 331 (2)
  Non-associated companies191 407 (53)
Total6,277 6,213 1 

See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2021 to the nine months ended September 30, 2020:
Amount
(In Millions)
2020 operating revenues$1,206.5 
Fuel, rider, and other revenues that do not significantly affect net income137.6 
Retail electric price92.0 
Volume/weather16.2 
2021 operating revenues$1,452.3 

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 retail electric price variance is primarily due to the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.

The volume/weather variance is primarily due to an increase of 713 GWh, or 5%, in billed electricity usage, including an increase in industrial and commercial usage and the effect of more favorable weather on residential sales. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from cogeneration customers. The increase in commercial usage is primarily due to the effects of Hurricane Laura in the third quarter of 2020. The
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increase is partially offset by a decrease in usage from residential customers primarily due to the impact that the COVID-19 pandemic had on prior year usage. See “Hurricane Laura and Hurricane Delta” above for discussion of the impacts from Hurricane Laura. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Billed electric energy sales for Entergy Texas for the nine months ended September 30, 2021 and 2020 are as follows:
20212020% Change
(GWh)
Residential4,876 4,782 2 
Commercial3,375 3,309 2 
Industrial6,530 5,970 9 
Governmental188 195 (4)
  Total retail 14,969 14,256 5 
Sales for resale:
  Associated companies983 895 10 
  Non-associated companies824 717 15 
Total16,776 15,868 6 

See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.

Other Income Statement Variances

Third Quarter 2021 Compared to Third Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $5.6 million in non-nuclear generation expenses primarily due to higher long-term service agreement expenses and other expenses associated with the Montgomery County Power Station, which began commercial operation in January 2021, and a higher scope of work performed in 2021 as compared to the same period in 2020;
•an increase of $1.6 million in transmission expenses primarily due to a higher scope of contract work, including vegetation maintenance; and
•an increase of $1.1 million in distribution operations expenses primarily due to higher contactor costs, partially offset by lower vegetation maintenance costs.

The increase was partially offset by a decrease of $1.8 million in meter reading expenses as a result of the deployment of advanced metering systems.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes, a sales tax audit assessment in the third quarter of 2021, and an increase in local franchise taxes. Ad valorem taxes increased as a result of higher assessments, primarily due to the addition of the Montgomery County Power Station.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.

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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 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $11.8 million in non-nuclear generation expenses primarily due to higher long-term service agreement expenses and other expenses associated with the Montgomery County Power Station, which began commercial operation in January 2021, and a higher scope of work performed in 2021 as compared to the same period in 2020;
•an increase of $3.1 million in distribution operations expenses primarily due to higher contractor costs and higher vegetation maintenance costs;
•an increase of $2.9 million in customer service costs primarily due to an increase in contract work in 2021 as compared to the same period in 2020;
•an increase of $2.1 million as a result of the amount of transmission costs allocated by MISO; and
•an increase of $2.1 million in compensation and benefits costs in 2021 primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and 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.

The increase was partially offset by a decrease of $4.3 million in meter reading expenses as a result of the deployment of advanced metering systems.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes, a sales tax audit assessment in the third quarter of 2021, and an increase in local franchise taxes. Ad valorem taxes increased as a result of higher assessments, primarily due to the addition of the Montgomery County Power Station.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.

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 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

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 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Income Taxes

The effective income tax rate was 13.7% for the third quarter 2021 and 11.3% for the nine months ended September 30, 2021. The differences in the effective income tax rates for the third quarter 2021 and the nine months ended September 30, 2021 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. 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 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.

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 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Cash and cash equivalents at beginning of period$248,596 $12,929 
Cash flow provided by (used in):
Operating activities254,980 294,253 
Investing activities(479,166)(657,427)
Financing activities(24,385)350,279 
Net decrease in cash and cash equivalents(248,571)(12,895)
Cash and cash equivalents at end of period$25 $34 

Operating Activities

Net cash flow provided by operating activities decreased $39.3 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•increased fuel costs, including those related to Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;
•the timing of payments to vendors; and
•an increase of approximately $18.9 million in storm spending in 2021, primarily due to Hurricane Laura and Hurricane Delta restoration efforts. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts.

The decrease was partially offset by the timing of collections of receivables from customers.


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Investing Activities

Net cash flow used in investing activities decreased $178.3 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•a decrease of $136.4 million in non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station project;
•a decrease of $80.4 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 2021 as compared to 2020; and
•the sale of a 7.56% partial interest in the Montgomery County Power Station in June 2021 for approximately $67.9 million. See Note 14 to the financial statements herein for further discussion of the transaction.

The decrease was partially offset by:

•an increase of $56.7 million in distribution construction expenditures primarily due to storm spending in 2021, partially offset by lower spending in 2021 on advanced metering infrastructure. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts; and
•the purchase of the Hardin County Peaking Facility in June 2021 for approximately $36.7 million. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

Financing Activities

Entergy Texas’s financing activities used $24.4 million of cash for the nine months ended September 30, 2021 compared to providing $350.3 million for the nine months ended September 30, 2020 primarily due to the following activity:

•the repayment, prior to maturity, of $125 million of 2.55% Series mortgage bonds in May 2021 and the repayment, at maturity, of $75 million of 4.10% Series mortgage bonds in September 2021;
•a capital contribution of $85 million received from Entergy Corporation in April 2021 in order to maintain Entergy Texas’s capital structure and in anticipation of various upcoming capital expenditures as compared to a capital contribution of $175 million received from Entergy Corporation in March 2020 in anticipation of upcoming expenditures, including Montgomery County Power Station;
•the issuance of $130 million of 1.50% Series mortgage bonds in August 2021 as compared to the issuance of $175 million of 3.55% Series mortgage bonds in March 2020; 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 $20.1 million for the nine months ended September 30, 2021 compared to increasing by $54.2 million for the nine months ended September 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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 Texas’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the net repayment of long-term debt in 2021 and the $85 million capital contribution received from Entergy Corporation in April 2021.
September 30,
2021		December 31,
2020
Debt to capital49.3 %53.7 %
Effect of excluding the securitization bonds(0.6 %)(1.3 %)
Debt to capital, excluding securitization bonds (a)48.7 %52.4 %
Effect of subtracting cash— %(2.7 %)
Net debt to net capital, excluding securitization bonds (a)48.7 %49.7 %

(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 is developing its capital investment plan for 2022 through 2024 and currently anticipates making $2.5 billion in capital investments during that period. The preliminary estimate includes generation projects to modernize, decarbonize, and diversify Entergy Texas’s portfolio, such as the Orange County Advanced Power Station; distribution and Utility support spending to deliver reliability, resilience, and customer experience; transmission spending to drive reliability and resilience and support customers’ sustainability goals for renewable expansion; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:
September 30,
2021		December 31,
2020		September 30,
2020		December 31,
2019
(In Thousands)
($20,075)$4,601($54,229)$11,181

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

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Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in June 2026.  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, 2021, 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, 2021, $12 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. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. In July 2021 the presiding ALJs issued a proposal for decision recommending that the PUCT deny the certification requested in the application. In October 2021 the PUCT issued an order adopting the ALJs’ proposal for decision and denying Entergy Texas’s application. Entergy Texas is reviewing the order and evaluating its options.

Orange County Advanced Power Station

In September 2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to construct, own, and operate the Orange County Advanced Power Station, a new 1,215 MW combined-cycle combustion turbine facility to be located in Bridge City, Texas at an expected total cost of $1.19 billion inclusive of the estimated costs of the generation facilities, transmission upgrades, contingency, an allowance for funds used during construction, and necessary regulatory expenses, among others. The project includes combustion turbine technology with dual fuel capability, able to co-fire up to 30% hydrogen by volume upon commercial operation and upgradable to support 100% hydrogen operations in the future. Subject to receipt of required regulatory approvals and other conditions, the facility is expected to be in-service by May 2026.

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

As discussed in the Form 10-K, 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 then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the ALJ with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement.

In August 2021, 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 $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. A procedural schedule was established with a
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hearing scheduled in December 2021.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, 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 then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the ALJ granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement.

In October 2021, 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 $66.1 million annually, or $15.1 million in incremental annual revenues beyond Energy Texas’s currently effective TCRF rider based on its capital invested in transmission between September 1, 2020 and July 31, 2021 and changes in approved transmission charges.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding and in May 2021 the ALJ issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the ALJ with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the ALJ. In October 2021, Entergy Texas filed on behalf of the parties an unopposed settlement agreement that would adjust its generation cost recovery rider to recover its investment in the Montgomery County Power Station through January 1, 2021, with Entergy Texas able to seek recovery of the remainder of its investment in its next base rate case. Also in October 2021 the ALJ granted a motion to admit evidence and remand the proceeding to the PUCT.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings for
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further processing. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. 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. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of September 30, 2021, Entergy Texas had a regulatory asset of $12.8 million for costs associated with the COVID-19 pandemic.

Fuel and purchased power recovery

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

Storm Cost Filings

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

In August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing included only a portion of the Winter Storm Uri costs. The filing also included the projected balance of $13 million of a regulatory asset containing previously approved system restoration costs related to Hurricane Harvey. In September 2021 the parties filed an unopposed settlement agreement pursuant to which, if approved, Entergy Texas would remove from the amount it proposed to securitize approximately $4.3 million that would instead be charged to its storm reserve, $5 million related to no particular issue, of which Entergy Texas would be permitted to seek recovery in a future proceeding, and $300 thousand related to attestation costs.

In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of the system restoration costs that are the subject of the April 2021 application. A procedural schedule was established with a deadline to file a settlement agreement or status update by November 11, 2021 and a supplemental procedural schedule if no settlement is filed within seven days of a PUCT final order in Entergy Texas’s system restoration cost proceeding.
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Federal Regulation

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

Nuclear Matters

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

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.

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, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$541,632 $494,922 $1,452,286 $1,206,452 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale92,843 96,902 269,270 186,038 
Purchased power155,723 139,204 425,784 383,346 
Other operation and maintenance68,973 60,423 202,743 179,883 
Taxes other than income taxes30,479 15,642 73,025 55,438 
Depreciation and amortization54,711 45,195 159,234 131,596 
Other regulatory charges (credits) - net10,029 29,250 51,122 69,342 
TOTAL412,758 386,616 1,181,178 1,005,643 
OPERATING INCOME128,874 108,306 271,108 200,809 
OTHER INCOME
Allowance for equity funds used during construction1,836 10,875 6,951 33,117 
Interest and investment income204 203 632 975 
Miscellaneous - net(507)2,061 (1,457)924 
TOTAL1,533 13,139 6,126 35,016 
INTEREST EXPENSE
Interest expense21,220 22,648 66,157 68,643 
Allowance for borrowed funds used during construction(738)(4,673)(2,797)(14,231)
TOTAL20,482 17,975 63,360 54,412 
INCOME BEFORE INCOME TAXES109,925 103,470 213,874 181,413 
Income taxes15,084 11,306 24,185 9,674 
NET INCOME94,841 92,164 189,689 171,739 
Preferred dividend requirements470 470 1,411 1,411 
EARNINGS APPLICABLE TO COMMON STOCK$94,371 $91,694 $188,278 $170,328 
See Notes to Financial Statements.


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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$189,689 $171,739 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization159,234 131,596 
Deferred income taxes, investment tax credits, and non-current taxes accrued31,518 37,072 
Changes in assets and liabilities:
Receivables(50,538)(55,059)
Fuel inventory7,232 (1,726)
Accounts payable20,506 15,542 
Taxes accrued6,003 (12,623)
Interest accrued(12,808)(7,855)
Deferred fuel costs(103,013)61,995 
Other working capital accounts(19,522)(8,382)
Provisions for estimated losses67 (69)
Other regulatory assets72,760 42,904 
Other regulatory liabilities(21,469)(39,791)
Pension and other postretirement liabilities(16,489)(18,179)
Other assets and liabilities(8,190)(22,911)
Net cash flow provided by operating activities254,980 294,253 
INVESTING ACTIVITIES
Construction expenditures(541,161)(703,650)
Allowance for equity funds used during construction6,951 33,117 
Proceeds from sale of assets67,920 — 
Payment for purchase of assets(36,534)(4,931)
Changes in money pool receivable - net4,601 11,181 
Changes in securitization account19,057 6,856 
Net cash flow used in investing activities(479,166)(657,427)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt127,931 344,110 
Retirement of long-term debt(269,435)(216,266)
Capital contribution from parent85,000 175,000 
Changes in money pool payable - net20,075 54,229 
Preferred stock dividends paid(1,411)(1,594)
Other13,455 (5,200)
Net cash flow provided by (used in) financing activities(24,385)350,279 
Net decrease in cash and cash equivalents(248,571)(12,895)
Cash and cash equivalents at beginning of period248,596 12,929 
Cash and cash equivalents at end of period$25 $34 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$77,110 $75,129 
Income taxes$11,710 $8,331 
See Notes to Financial Statements.
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$25 $26 
Temporary cash investments— 248,570 
Total cash and cash equivalents25 248,596 
Securitization recovery trust account17,176 36,233 
Accounts receivable:
Customer115,016 103,221 
Allowance for doubtful accounts(9,013)(16,810)
Associated companies23,175 18,892 
Other20,383 11,780 
Accrued unbilled revenues69,870 56,411 
Total accounts receivable219,431 173,494 
Deferred fuel costs17,657 — 
Fuel inventory - at average cost46,299 53,531 
Materials and supplies - at average cost75,584 56,227 
Prepayments and other23,736 20,165 
TOTAL399,908 588,246 
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity312 349 
Non-utility property - at cost (less accumulated depreciation)376 376 
Other17,936 19,889 
TOTAL18,624 20,614 
UTILITY PLANT
Electric7,044,218 6,007,687 
Construction work in progress158,458 879,908 
TOTAL UTILITY PLANT7,202,676 6,887,595 
Less - accumulated depreciation and amortization2,017,029 1,864,494 
UTILITY PLANT - NET5,185,647 5,023,101 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $35,886 as of September 30, 2021 and $78,590 as of December 31, 2020)
451,953 524,713 
Other85,261 70,397 
TOTAL537,214 595,110 
TOTAL ASSETS$6,141,393 $6,227,071 
See Notes to Financial Statements.  
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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$— $200,000 
Accounts payable:
Associated companies70,050 55,944 
Other173,719 350,947 
Customer deposits34,092 36,282 
Taxes accrued58,441 52,438 
Interest accrued8,048 20,856 
Current portion of unprotected excess accumulated deferred income taxes33,192 29,249 
Deferred fuel costs— 85,356 
Other18,201 12,370 
TOTAL395,743 843,442 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued676,521 639,422 
Accumulated deferred investment tax credits9,479 9,942 
Regulatory liability for income taxes - net142,539 175,594 
Other regulatory liabilities39,940 32,297 
Asset retirement cost liabilities8,403 8,063 
Accumulated provisions8,449 8,382 
Long-term debt (includes securitization bonds of $53,941 as of September 30, 2021 and $123,066 as of December 31, 2020)
2,353,742 2,293,708 
Other75,721 58,643 
TOTAL3,314,794 3,226,051 
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2021 and 2020
49,452 49,452 
Paid-in capital1,040,162 955,162 
Retained earnings1,306,242 1,117,964 
Total common shareholder's equity2,395,856 2,122,578 
Preferred stock without sinking fund35,000 35,000 
TOTAL2,430,856 2,157,578 
TOTAL LIABILITIES AND EQUITY$6,141,393 $6,227,071 
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, 2021 and 2020
(Unaudited)
Common Equity
Preferred StockCommon
Stock		Paid-in
Capital		Retained
Earnings		Total
(In Thousands)
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, 2020$35,000 $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, 2020$35,000 $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 
Balance at December 31, 2020$35,000 $49,452 $955,162 $1,117,964 $2,157,578 
Net income— — — 50,058 50,058 
Preferred stock dividends— — — (470)(470)
Balance at March 31, 2021$35,000 $49,452 $955,162 $1,167,552 $2,207,166 
Net income— — — 44,790 44,790 
Capital contribution from parent— — 85,000 — 85,000 
Preferred stock dividends— — — (471)(471)
Balance at June 30, 2021$35,000 $49,452 $1,040,162 $1,211,871 $2,336,485 
Net income— — — 94,841 94,841 
Preferred stock dividends— — — (470)(470)
Balance at September 30, 2021$35,000 $49,452 $1,040,162 $1,306,242 $2,430,856 
See Notes to Financial Statements.
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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 2021 Compared to Third Quarter 2020

Net income decreased $3.6 million primarily due to the decrease in operating revenues resulting from changes in rate base.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Net income decreased $6.9 million primarily due to the decrease in operating income resulting from changes in rate base.

Income Taxes

The effective income tax rate was 23.5% for the third quarter 2021. The difference in the effective income tax rate for the third quarter 2021 versus the federal statutory rate of 21% was primarily due to state income taxes.

The effective income tax rate was 7.7% for the nine months ended September 30, 2021. The difference in the effective income tax rate for the nine months ended September 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, 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.

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 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.


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Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2021 and 2020 were as follows:
20212020
(In Thousands)
Cash and cash equivalents at beginning of period$242,469 $68,534 
Cash flow provided by (used in):
Operating activities130,676 159,300 
Investing activities(75,603)(179,267)
Financing activities(134,400)(36,636)
Net decrease in cash and cash equivalents(79,327)(56,603)
Cash and cash equivalents at end of period$163,142 $11,931 

Operating Activities

Net cash flow provided by operating activities decreased $28.6 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to income tax payments of $39.1 million in 2021 and timing of collections of receivables, partially offset by a decrease in spending of $37.2 million on nuclear refueling outages in 2021 as compared to the same period in 2020 and timing of payments to vendors. System Energy had income tax payments in 2021 as a result of the amended Mississippi tax returns filed based on federal adjustments related to the resolution of the 2014-2015 IRS audit, as well as a portion of the payments made in accordance with an intercompany income tax allocation agreement. See Note 3 to the financial statements in the Form 10-K for discussion of the 2014-2015 IRS audit.

Investing Activities

Net cash flow used in investing activities decreased $103.7 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to:

•a decrease of $109.1 million in nuclear construction expenditures as a result of spending in 2020 on Grand Gulf outage projects and upgrades; and
•an increase of $59.7 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.

The decrease was partially offset by money pool activity.

Increases in System Energy’s receivable from the money pool are a use of cash flow and System Energy’s receivable from the money pool increased by $8.3 million for the nine months ended September 30, 2021 compared to decreasing by $58.3 million for the nine months ended September 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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Financing Activities

Net cash flow used by financing activities increased $97.8 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to the repayment in February 2021 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the net repayment of long-term debt in 2021.
 September 30,
2021		December 31,
2020
Debt to capital40.7 %42.7 %
Effect of subtracting cash(5.8 %)(8.5 %)
Net debt to net capital34.9 %34.2 %

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.

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 2022 through 2024 and currently anticipates making $510 million in capital investments during that period. The preliminary estimate includes amounts associated with Grand Gulf investments and initiatives.

System Energy’s receivables from the money pool were as follows:
September 30,
2021		December 31,
2020		September 30,
2020		December 31, 2019
(In Thousands)
$12,338$4,004$1,021$59,298

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

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The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in June 2024. As of September 30, 2021, $40.7 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 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. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $60 million, which includes interest through September 30, 2021, and the estimated resulting annual rate reduction would be approximately $45 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has a provision recorded of $37 million, including interest, as of September 30, 2021.

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. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

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. 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
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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 that 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, 2021, is approximately $422 million, plus interest, which is approximately $123 million through September 30, 2021. 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, 2021.

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. 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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, 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 the FERC “necessary to address these rate
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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.”

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first 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. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay has expired.

In August 2021 the FERC issued an order addressing System Energy’s and the complainants’ rehearing requests. The FERC dismissed part of the complaint seeking an equity reopener, maintained the abeyance for issues related to the proceeding addressing the sale-leaseback renewal and uncertain tax positions, lifted the abeyance for issues unrelated to that proceeding, and clarified the scope of the hearing. A procedural schedule was established, with the hearing scheduled for June 2022 and the ALJ’s initial decision scheduled for November 2022. Discovery is ongoing.

Grand Gulf Prudence Complaint

The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications
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to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants and System Energy during the period from March through July 2021.

Nuclear Matters

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

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.

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC conducted a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3 and, in October 2021, notified Entergy that all inspection objectives were met. A formal report on the inspection is expected in late 2021.

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, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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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INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2021 and 2020
(Unaudited)
Three Months EndedNine Months Ended
2021202020212020
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$154,319 $148,517 $433,378 $405,230 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale15,279 13,620 46,211 32,771 
Nuclear refueling outage expenses6,867 6,942 20,377 20,880 
Other operation and maintenance54,709 48,902 154,716 132,175 
Decommissioning9,721 9,341 28,875 27,746 
Taxes other than income taxes7,268 7,203 21,061 22,281 
Depreciation and amortization25,991 28,006 79,953 82,406 
Other regulatory charges (credits) - net(1,707)(14,393)(7,707)(28,470)
TOTAL118,128 99,621 343,486 289,789 
OPERATING INCOME 36,191 48,896 89,892 115,441 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction1,546 1,206 4,012 7,990 
Interest and investment income11,839 1,303 36,871 18,749 
Miscellaneous - net(4,372)(3,354)(14,282)(7,971)
TOTAL9,013 (845)26,601 18,768 
INTEREST EXPENSE
Interest expense9,513 8,427 28,627 25,501 
Allowance for borrowed funds used during construction(261)(240)(678)(1,585)
TOTAL9,252 8,187 27,949 23,916 
INCOME BEFORE INCOME TAXES35,952 39,864 88,544 110,293 
Income taxes8,453 8,800 6,851 21,725 
NET INCOME$27,499 $31,064 $81,693 $88,568 
See Notes to Financial Statements.

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STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2021 and 2020
(Unaudited)
20212020
(In Thousands)
OPERATING ACTIVITIES
Net income$81,693 $88,568 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization151,345 137,201 
Deferred income taxes, investment tax credits, and non-current taxes accrued17,233 (272,383)
Changes in assets and liabilities:
Receivables(5,216)15,637 
Accounts payable(4,292)(19,775)
Taxes accrued(35,063)431,677 
Interest accrued(1,557)(188)
Other working capital accounts5,133 (40,566)
Other regulatory assets71,486 (25,956)
Other regulatory liabilities31,909 45,657 
Pension and other postretirement liabilities(20,721)(11,033)
Other assets and liabilities(161,274)(189,539)
Net cash flow provided by operating activities130,676 159,300 
INVESTING ACTIVITIES
Construction expenditures(64,196)(169,475)
Allowance for equity funds used during construction4,012 7,990 
Nuclear fuel purchases(27,958)(85,483)
Proceeds from the sale of nuclear fuel21,657 19,444 
Proceeds from nuclear decommissioning trust fund sales769,979 322,982 
Investment in nuclear decommissioning trust funds(770,763)(333,002)
Changes in money pool receivable - net(8,334)58,277 
Net cash flow used in investing activities(75,603)(179,267)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt565,610 859,727 
Retirement of long-term debt(626,010)(815,710)
Common stock dividends and distributions paid(74,000)(80,653)
Net cash flow used in financing activities(134,400)(36,636)
Net decrease in cash and cash equivalents(79,327)(56,603)
Cash and cash equivalents at beginning of period242,469 68,534 
Cash and cash equivalents at end of period$163,142 $11,931 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$30,335 $17,178 
Income taxes$39,085 ($4,000)
See Notes to Financial Statements.
199
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$106 $26,086 
Temporary cash investments163,036 216,383 
Total cash and cash equivalents163,142 242,469 
Accounts receivable:
Associated companies68,737 57,743 
Other5,106 2,550 
Total accounts receivable73,843 60,293 
Materials and supplies - at average cost139,702 123,006 
Deferred nuclear refueling outage costs15,289 34,459 
Prepayments and other4,200 6,864 
TOTAL396,176 467,091 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,310,462 1,215,868 
TOTAL1,310,462 1,215,868 
UTILITY PLANT
Electric5,324,544 5,309,458 
Construction work in progress97,655 59,831 
Nuclear fuel134,880 175,005 
TOTAL UTILITY PLANT5,557,079 5,544,294 
Less - accumulated depreciation and amortization3,374,953 3,355,367 
UTILITY PLANT - NET2,182,126 2,188,927 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets467,477 538,963 
Other2,183 3,119 
TOTAL469,660 542,082 
TOTAL ASSETS$4,358,424 $4,413,968 
See Notes to Financial Statements.
200
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2021 and December 31, 2020
(Unaudited)
20212020
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$50,329 $100,015 
Accounts payable:
Associated companies17,011 15,309 
Other40,780 41,313 
Taxes accrued47,914 82,977 
Interest accrued11,165 12,722 
Other4,243 4,248 
TOTAL171,442 256,584 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued371,438 359,835 
Accumulated deferred investment tax credits43,323 38,902 
Regulatory liability for income taxes - net131,176 151,829 
Other regulatory liabilities717,958 665,396 
Decommissioning997,785 968,910 
Pension and other postretirement liabilities104,691 125,412 
Long-term debt695,443 705,259 
Other36,929 61,295 
TOTAL3,098,743 3,076,838 
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2021 and 2020
951,850 951,850 
Retained earnings136,389 128,696 
TOTAL1,088,239 1,080,546 
TOTAL LIABILITIES AND EQUITY$4,358,424 $4,413,968 
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, 2021 and 2020
(Unaudited)
Common Equity
Common
Stock		Retained
Earnings		Total
(In Thousands)
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, 2020$601,850 $125,078 $726,928 
Net income— 28,991 28,991 
Common stock dividends and distributions— (46,000)(46,000)
Balance at June 30, 2020$601,850 $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 
Balance at December 31, 2020$951,850 $128,696 $1,080,546 
Net income— 23,864 23,864 
Common stock dividends and distributions— (21,000)(21,000)
Balance at March 31, 2021$951,850 $131,560 $1,083,410 
Net income— 30,330 30,330 
Common stock dividends and distributions— (5,000)(5,000)
Balance at June 30, 2021$951,850 $156,890 $1,108,740 
Net income— 27,499 27,499 
Common stock dividends and distributions— (48,000)(48,000)
Balance at September 30, 2021$951,850 $136,389 $1,088,239 
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 factors 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 impacts of the COVID-19 pandemic 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, several variants of the COVID-19 virus have spread throughout the world, including the United States. To mitigate the spread of COVID-19, public health officials in the United States have at various times both recommended and mandated wearing of masks and other precautions, including prohibitions on congregating in heavily-populated areas, 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 many of these mitigation measures have been lifted following the wide availability of COVID-19 vaccines, there is a risk that certain of these measures could be reinstated and/or continued, and that such measures could have an adverse effect on the general economy, Entergy’s customers, and its operations.

Entergy and its Utility operating companies experienced a decline in commercial and industrial sales and an increase in arrearages and bad debt expense due to non-payment by customers. Much of the commercial and industrial sales have recovered, and the arrearages have begun to decline, although management cannot predict the timing of collections of such arrearages. The Utility operating companies have resumed disconnecting customers for non-payment of bills, but such disconnects could again be suspended at the Utility operating companies should another shelter-in-place order or similar measure occur and their regulators mandate. While they are working with regulators to ensure ultimate recovery for those and other COVID-19 related costs, the amount, method, and timing of such recovery is unknown. 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 challenges, including from COVID-19 infections, quarantining, or concerns with vaccination or testing mandates, health or safety issues; increased storm recovery costs; increased cybersecurity risks as a result of many employees telecommuting; risks or uncertainties associated with the return for many employees from telecommuting to on-site work on a full-time or hybrid basis; 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.

Although the economy has been recovering, another 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. The Utility operating companies also may experience regulatory outcomes that require them to postpone planned investment and otherwise reduce costs due to the impact of the COVID-19 pandemic on their customers. In addition, if the COVID-19 pandemic creates additional disruptions or 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
203
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 impact of new variants of COVID-19, the effectiveness of mitigation efforts, or vaccines, 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.

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

A delay or failure in recovering amounts for storm restoration costs incurred as a result of severe weather (including from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Hurricane Ida), or the impact on customer bills of permitted storm cost recovery, could have material effects on Entergy and its Utility operating companies.

Entergy’s and its Utility operating companies’ results of operations, liquidity, and financial condition can be materially affected by the destructive effects of severe weather. Severe weather can also result in significant outages for the customers of the Utility operating companies and, therefore, reduced revenues for the Utility operating companies during the period of the outages. A delay or failure in recovering amounts for storm restoration costs incurred or revenues lost as a result of severe weather could have a material effect on Entergy and those Utility operating companies affected by severe weather. In addition, the recovery of major storm restoration costs from customers could effectively limit our ability to make planned capital or other investments due to the impact of such storm cost recovery on customer bills.

In August and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of the Utility’s service territories in Louisiana, including New Orleans, Texas, and to a lesser extent, Arkansas and Mississippi. The storms resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’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, Hurricane Delta, and Hurricane Zeta are currently estimated to be approximately $2.4 billion.

In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida are currently estimated to be in the range of $2.1 billion to $2.5 billion. Most of the storm costs were incurred by Entergy Louisiana and Entergy New Orleans. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.

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.


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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)
7/01/2021-7/31/2021— $— — $350,052,918 
8/01/2021-8/31/2021— $— — $350,052,918 
9/01/2021-9/30/2021— $— — $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 2021, Entergy withheld 81,434 shares of its common stock at $95.12 per share, 40,476 shares of its common stock at $95.15 per share, 36,804 shares of its common stock at $94.75 per share, 36,347 shares of its common stock at $95.33 per share, 1,188 shares of its common stock at $91.16 per share, 853 shares of its common stock at $96.47 per share, 719 shares of its common stock at $98.01 per share, 678 shares of its common stock at $92.70 per share, 584 shares of its common stock at $94.69 per share, 118 shares of its common stock at $95 per share, and 10 shares of its common stock at $95.25 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.

Nuclear Waste Policy Act of 1982

Nuclear Plant Decommissioning

In March 2021 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.

205
NRC Reactor Oversight Process

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC conducted a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3 and, in October 2021, notified Entergy that all inspection objectives were met. A formal report on the inspection is expected in late 2021.

Environmental Regulation

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

Clean Air Act and Subsequent Amendments

See the Form 10-K for discussion of the Clean Air Act and Subsequent Amendments set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

New Source Review

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims as well as other issues facing Entergy Arkansas’s fossil generation plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In March 2021 the District Court approved and entered the proposed settlement. For further information about the settlement, see “Regional Haze” discussed below.

National Ambient Air Quality Standards

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

Hazardous Air Pollutants

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. In February 2021 the D.C. Circuit granted the EPA’s motion to hold the litigation in abeyance pending the agency’s review of the appropriate and necessary rule. The EPA must file status reports with the court every 120 days. Entergy will continue to monitor this situation.

Cross-State Air Pollution

As discussed in the Form 10-K, the Cross-State Air Pollution Rule (CSAPR) has been remanded to and modified by the EPA on multiple occasions. In September 2016 the EPA finalized the CSAPR Update Rule to address interstate transport for the 2008 ozone NAAQS. In September 2019 the D.C. Circuit upheld the EPA’s underlying approach to the Update Rule, but determined that it was inconsistent with the Clean Air Act because it
206
failed to include deadlines consistent with the downward states’ deadlines for attainment. The court remanded the rule to the EPA for further consideration, but did not vacate it so the rule remains in effect pending the EPA’s further review. In April 2021, addressing the D.C. Circuit’s remand, the EPA finalized revisions to the Update Rule, which became effective June 29, 2021. The rule finalizes interstate transport obligations for 21 states. For 12 states, including Louisiana, the EPA further reduced the number of NOx emission allowances allocated to each state. Entergy is currently analyzing the potential impact on its facilities in Louisiana. Preliminary analysis indicates that ozone season NOx allowances may become more expensive in Louisiana, which could impact the cost of dispatching Entergy’s generating units located in Louisiana.

Regional Haze

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims and reducing the risk that Entergy Arkansas, as operator of Independence and White Bluff, might be compelled under the Clean Air Act’s regional haze program to install costly emissions control technologies. Consistent with the terms of the settlement and in many cases also the Part II state implementation plan (SIP), Entergy Arkansas, along with co-owners, agreed to begin using only low-sulfur coal at Independence and White Bluff by mid-2021; agreed to cease using coal at White Bluff and Independence by the end of 2028 and 2030, respectively; agreed to cease operation of the remaining gas unit at Lake Catherine by the end of 2027; reserved the option to develop new generating sources at each plant site; and committed to installing or proposing to regulators at least 800 MWs of renewable generation by the end of 2027, with at least half installed or proposed by the end of 2022 (which includes two existing Entergy Arkansas projects) and with all qualifying co-owner projects counting toward satisfaction of the obligation. Under the settlement, the Sierra Club and the National Parks Conservation Association also waived certain potential existing claims under federal and state environmental law with respect to specified generating plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In November 2020 the court denied motions by the Arkansas Attorney General and the Arkansas Affordable Energy Coalition to intervene and to stay the proceedings. The proposed intervenors did not appeal the ruling. The District Court approved and entered the proposed settlement in March 2021. Entergy met the settlement deadline to use low-sulfur coal, is on target to meet the other requirements of the settlement, and is in compliance with other SIP requirements.

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 July 31, 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. Louisiana has issued its draft SIP which does not propose any additional air emissions controls for Entergy units in Louisiana. However, some public commenters believe additional air controls are cost-effective. It is not yet clear how the Louisiana Department of Environmental Quality (LDEQ) will respond in its final SIP, and the agency, like many other state agencies, did not meet the July 31, 2021 deadline to submit a SIP to the EPA for review. The LDEQ is now expected to finalize its Regional Haze SIP in late 2021 or early 2022.

New and Existing Source Performance Standards for Greenhouse Gas Emissions

As discussed in the Form 10-K, in January 2021 the U.S. Court of Appeals for the D.C. Circuit vacated the Affordable Clean Energy Rule (ACE). The court held that ACE relied on an incorrect interpretation of the Clean Air Act that the statute expressly forecloses emission reduction approaches, such as emissions trading and generating shifting, that cannot be applied at and to the individual source. The court remanded ACE to the EPA for further consideration and also vacated the repeal of the Clean Power Plan. In March 2021 the D.C. Circuit issued a
207
partial mandate vacating the ACE rule, but withheld the mandate vacating the repeal of the Clean Power Plan pending the EPA’s new rulemaking to regulate greenhouse gas emissions. Thus, the Clean Power Plan will not take effect during the rulemaking process and there currently is no regulation in place with respect to greenhouse gas emissions from existing electric generating units and states are not expected to take further action to develop and submit plans at this time.

Federal Jurisdiction of Waters of the United States

In June 2020 the EPA’s revised definition of waters of the United States in the Navigable Waters Protection Rule (NWPR), which narrowed the scope of Clean Water Act jurisdiction, as compared to a 2015 definition which had been stayed by several federal courts became effective. In August 2021 a federal district court vacated and remanded the NWPR for further consideration. The EPA and the U.S. Army Corps of Engineers subsequently issued a statement that the agencies would revert to pre-2015 regulations pending a new rulemaking.

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 the new EPA regulations. Each site has commenced closure of its two recycle ponds (four ponds total), prior to the April 11, 2021 deadline under the finalized CCR rule for unlined recycle ponds.

Other Environmental Matters

Entergy Texas

As discussed in the Form 10-K, due to COVID-19 pandemic delays, the Texas Commission on Environmental Quality (TCEQ) extended the Affected Property Assessment Report (APAR) and Ecological Risk Assessment submittal dates to December 2020, which Entergy timely met. Following the TCEQ’s review of the APAR and Ecological Risk Assessment, the TCEQ issued a No Further Action determination for the site in March 2021.

Executive Compensation

On November 2, 2021, Entergy Corporation (the Company), entered into an agreement with its Chief Executive Officer, Leo P. Denault (Executive), to amend: (i) the Pension Equalization Plan of Entergy Corporation and its Subsidiaries, as amended (the PEP), to cease Executive’s participation therein effective December 1, 2021, if Executive has not separated from service with the Company before such date; and (ii) the System Executive Retirement Plan of Entergy Corporation and Subsidiaries, as amended (the SERP), to provide that, if Executive separates from service with the Company after November 30, 2021, the benefit payable to Executive (or his surviving spouse, if applicable) under the SERP will be determined as if Executive had separated from service on November 30, 2021 (including the use of compensation, service and actuarial assumptions applicable to separations as of such date). Except as amended, benefits payable to Executive (or his surviving spouse, if applicable) under the SERP otherwise generally continue to be subject to the provisions of the SERP (including applicable forfeiture conditions) and Executive’s Retention Agreement with the Company effective August 3, 2006, as amended.

Item 6.  Exhibits
4(a) -
Officer’s Certificate No. 18-B-14, dated August 11, 2021, supplemental to Indenture, Deed of Trust and Security Agreement, dated as of October 1, 2008, between Entergy Texas and The Bank of New York Mellon, as trustee (4.57 to Form 8-K filed August 17, 2021 in 1-34360).
4(b) -
Ninety-sixth Supplemental Indenture, dated as of October 1, 2021, to Entergy Louisiana Mortgage and Deed of Trust, dated as of April 1, 1944 (4.53 to Form 8-K filed October 1, 2021 in 1-32718).
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4(c) -
Ninety-fifth Supplemental Indenture, dated as of October 1, 2021, to Entergy Louisiana Indenture of Mortgage, dated September 1, 1926 (4.52 to Form 8-K filed October 1, 2021 in 1-32718).
4(d) -
Seventeenth Supplemental Indenture, dated as of October 1, 2021, to Entergy Louisiana Mortgage and Deed of Trust, dated as of November 1, 2015 (4.51 to Form 8-K filed October 1, 2021 in 1-32718).
4(e) -
Officer’s Certificate No. 24-B-18, dated September 28, 2021, supplemental to Mortgage and Deed of Trust of Entergy Louisiana, dated as of November 1, 2015 (4.50 to Form 8-K filed October 1, 2021 in 1-32718).
*31(a) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
*31(b) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
*31(c) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
*31(d) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
*31(e) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
*31(f) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
*31(g) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
*31(h) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
*31(i) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
*31(j) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
*31(k) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
*31(l) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
*31(m) -
Rule 13a-14(a)/15d-14(a) Certification for System Energy.
*31(n) -
Rule 13a-14(a)/15d-14(a) Certification for System Energy.
**32(a) -
Section 1350 Certification for Entergy Corporation.
**32(b) -
Section 1350 Certification for Entergy Corporation.
**32(c) -
Section 1350 Certification for Entergy Arkansas.
**32(d) -
Section 1350 Certification for Entergy Arkansas.
**32(e) -
Section 1350 Certification for Entergy Louisiana.
**32(f) -
Section 1350 Certification for Entergy Louisiana.
**32(g) -
Section 1350 Certification for Entergy Mississippi.
**32(h) -
Section 1350 Certification for Entergy Mississippi.
**32(i) -
**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.
209
Table of Contents
*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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Table of Contents
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 5, 2021

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