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ENTERGY NEW ORLEANS, LLC - Quarter Report: 2022 June (Form 10-Q)

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

FORM 10-Q
(Mark One)
☑QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2022
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)
2107 Research Forest Drive
The Woodlands, Texas 77380
Telephone (409) 981-2000
83-191866861-1435798
1-32718ENTERGY LOUISIANA, LLC1-09067SYSTEM ENERGY RESOURCES, INC.
(a Texas limited liability company)
4809 Jefferson Highway
Jefferson, Louisiana 70121
Telephone (504) 576-4000
(an Arkansas corporation)
1340 Echelon Parkway
Jackson, Mississippi 39213
Telephone (601) 368-5000
47-446964672-0752777
1-31508ENTERGY MISSISSIPPI, LLC
(a Texas limited liability company)
308 East Pearl Street
Jackson, Mississippi 39201
Telephone (601) 368-5000
83-1950019
__________________________________________________________________________________________


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



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

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).  Yes ☑ No ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.
Large accelerated filerAccelerated
filer		Non-accelerated filerSmaller
reporting
company		Emerging
growth
company
Entergy Corporationü
Entergy Arkansas, LLCü
Entergy Louisiana, LLCü
Entergy Mississippi, LLCü
Entergy New Orleans, LLCü
Entergy Texas, Inc.ü
System Energy Resources, Inc.ü

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

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

Common Stock OutstandingOutstanding at July 29, 2022
Entergy Corporation($0.01 par value)203,417,995

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, 2021 and the Quarterly Report on Form 10-Q for the quarter ended March 31, 2022, filed by the individual registrants with the SEC, and should be read in conjunction therewith.


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TABLE OF CONTENTS
Page Number
Part I. Financial Information
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy Arkansas, LLC and Subsidiaries
Entergy Louisiana, LLC and Subsidiaries
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Page Number
Entergy Mississippi, LLC and Subsidiaries
Entergy New Orleans, LLC and Subsidiaries
Entergy Texas, Inc. and Subsidiaries
System Energy Resources, Inc.
Statements of Operations
Part II. Other Information
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FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, 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 (a) those factors discussed or incorporated by reference in Item 1A. Risk Factors in the Form 10-K and in this report, (b) those factors discussed or incorporated by reference in 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;
•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, nuclear materials and fuel, 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, changing economic conditions, and emerging operating and industry issues, and the risks related to recovery of these costs and capital expenditures from Entergy’s customers (especially in an increasing cost environment);
•the commitment of substantial human and capital resources required for the safe and reliable operation and maintenance of Entergy’s nuclear generating facilities;
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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 and related laws, regulations, and other governmental actions;
•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, 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;
•effects of climate change, including the potential for increases in extreme weather events and sea levels or coastal land and wetland loss;
•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 and a utility industry mutual insurance company;
•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;
•the effects of supply chain disruptions, including those driven by the COVID-19 global pandemic or by trade-related governmental actions, on Entergy’s ability to complete its capital projects in a timely and cost-effective manner;
•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 inflation, and the risk that anticipated load growth may not materialize;
•changes to federal income tax laws and regulations, including the Senate-proposed Inflation Reduction Act of 2022, and including the 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 and cost of capital and Entergy’s ability to refinance existing securities and fund investments and acquisitions;
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FORWARD-LOOKING INFORMATION (Concluded)

•actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;
•changes in inflation and interest rates;
•the 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 or geopolitical event or pandemic, such as the COVID-19 global pandemic and the military activities between Russia and Ukraine, 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 effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments; and
•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that they may undertake.


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DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:
Abbreviation or AcronymTerm
ALJ
Administrative Law Judge
ANO 1 and 2
Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC
Arkansas Public Service Commission
ASU
Accounting Standards Update issued by the FASB
Board
Board of Directors of Entergy Corporation
Cajun
Cajun Electric Power Cooperative, Inc.
capacity factor
Actual plant output divided by maximum potential plant output for the period
City Council
Council of the City of New Orleans, Louisiana
COVID-19
The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
D.C. Circuit
U.S. Court of Appeals for the District of Columbia Circuit
DOE
United States Department of Energy
Entergy
Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation
Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.
Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana
Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes.  The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires. Effective October 1, 2015, the business of Entergy Gulf States Louisiana was combined with Entergy Louisiana.
Entergy Louisiana
Entergy Louisiana, LLC, a Texas limited liability company formally created as part of the combination of Entergy Gulf States Louisiana and the company formerly known as Entergy Louisiana, LLC (Old Entergy Louisiana) into a single public utility company and the successor to Old Entergy Louisiana for financial reporting purposes.
Entergy Texas
Entergy Texas, Inc., a Texas corporation formally created as part of the jurisdictional separation of Entergy Gulf States, Inc.  The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale Commodities
Entergy’s non-utility business segment primarily comprised of the ownership, operation, and decommissioning of nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by its operating power plants to wholesale customers. With the sale of Palisades in June 2022, Entergy completed its multi-year strategy to exit the merchant nuclear power business.
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, 2021 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
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DEFINITIONS (Continued)
Abbreviation or AcronymTerm
GWh
Gigawatt-hour(s), which equals one million kilowatt-hours
HLBVHypothetical liquidation at book value
Independence
Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC
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
LURC
Louisiana Utilities Restoration Corporation
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), which equals one thousand kilowatts
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
NRC
Nuclear Regulatory Commission
Palisades
Palisades Nuclear Plant (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2022 and was sold in June 2022
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
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.
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DEFINITIONS (Concluded)
Abbreviation or AcronymTerm
System Energy
System Energy Resources, Inc.
TWh
Terawatt-hour(s), which equals one billion kilowatt-hours
Unit Power Sales Agreement
Agreement, dated as of June 10, 1982, as amended and approved by the FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility
Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Vermont Yankee
Vermont Yankee Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in December 2014 and was disposed of in January 2019
Waterford 3
Unit No. 3 (nuclear) of the Waterford Steam Electric Station, owned by Entergy Louisiana
weather-adjusted usage
Electric usage excluding the effects of deviations from normal weather
White Bluff
White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas
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ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

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

•The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business.
•The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants. With the sale of Palisades in June 2022, Entergy completed its multi-year strategy to exit the merchant nuclear power business.

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

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

Second Quarter 2022 Compared to Second Quarter 2021

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the second quarter 2022 to the second quarter 2021 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)
2021 Net Income (Loss) Attributable to Entergy Corporation$325,903 ($275,195)($56,682)($5,974)
Operating revenues632,884 (59,723)(35)573,126 
Fuel, fuel-related expenses, and gas purchased for resale18,570 7,317 (5)25,882 
Purchased power310,321 7,930 5 318,256 
Other regulatory charges (credits) - net816,201 — — 816,201 
Other operation and maintenance34,446 (40,848)2,999 (3,403)
Asset write-offs, impairments, and related charges (credits)— (506,158)— (506,158)
Taxes other than income taxes19,567 (3,239)5 16,333 
Depreciation and amortization34,891 (11,172)(505)23,214 
Other income (deductions)(5,315)(59,299)(10,647)(75,261)
Interest expense10,621 (2,288)5,152 13,485 
Other expenses(596)(29,527)— (30,123)
Income taxes(443,064)96,929 4,908 (341,227)
Preferred dividend requirements of subsidiaries and noncontrolling interest(224)— (48)(272)
2022 Net Income (Loss) Attributable to Entergy Corporation$152,739 $86,839 ($79,875)$159,703 

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

Second quarter 2022 results of operations include: 1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued as part of the securitization regulatory proceeding; and 3) a gain of $166 million ($130 million net-of-tax) as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements herein for further discussion of the System Energy partial settlement agreement and offer of settlement. See Notes 2 and 10 to the financial statements herein for further discussion of the securitization. See Note 14 to the financial statements herein for further discussion of the sale of the Palisades plant.

Second quarter 2021 results of operations 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 in the Form 10-K for further discussion of the sale of the Indian Point Energy Center.
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Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the second quarter 2022 to the second quarter 2021:
Amount
(In Millions)
2021 operating revenues$2,673 
Fuel, rider, and other revenues that do not significantly affect net income376 
Volume/weather140 
Storm restoration carrying costs59 
Retail electric price58 
2022 operating revenues$3,306 

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

The volume/weather variance is primarily due to an increase of 2,343 GWh, or 8%, in electricity usage across all customer classes, including the effect of more favorable weather on residential and commercial sales. The increase in industrial usage was due to an increase in demand from expansion projects, primarily in the chemicals, transportation, and petroleum refining industries, an increase in demand from cogeneration customers, and an increase in demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns. The increase in weather-adjusted commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in second quarter 2021.

Storm restoration carrying costs, representing the equity component of storm restoration carrying costs, includes $37 million at Entergy Louisiana and $22 million at Entergy Texas, recorded in second quarter 2022, recognized as part of the Entergy Louisiana storm cost securitization in May 2022 and the Entergy Texas storm cost securitization in April 2022. See Note 2 to the financial statements herein for discussion of storm cost securitizations.

The retail electric price variance is primarily due to:

•an increase in Entergy Arkansas’s formula rate plan rates effective January 2022;
•an increase in Entergy Louisiana’s formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective September 2021;
•increases in Entergy Mississippi’s formula rate plan rates effective July 2021 and April 2022;
•an increase in Entergy New Orleans’s formula rate plan rates effective November 2021; and
•an increase in the transmission cost recovery factor rider effective March 2022 and an increase in the distribution cost recovery factor rider effective January 2022, 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.



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Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis

Total electric energy sales for Utility for the three months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential9,493 8,487 12 
Commercial7,203 6,731 7 
Industrial13,480 12,640 7 
Governmental641 616 4 
Total retail30,817 28,474 8 
Sales for resale3,920 4,716 (17)
Total34,737 33,190 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 $149 million for the second quarter 2021 to $89 million for the second quarter 2022 primarily due to the shutdown of Palisades in May 2022 and Indian Point 3 in April 2021 and lower realized wholesale energy and capacity prices including the effect of the additional PPA entered into with Consumers Energy covering the period from April 2022 to final shutdown in May 2022 at a lower rate than the original PPA. See Note 19 to the financial statements in the Form 10-K for further discussion of the Palisades PPA.

Following are key performance measures for Entergy Wholesale Commodities for the second quarters 2022 and 2021:
20222021
Owned capacity (MW) (a)3941,205
GWh billed1,3712,687
Entergy Wholesale Commodities Nuclear Fleet (b)
Capacity factor81%94%
GWh billed9752,356
Average energy price ($/MWh)$30.50$48.75
Average capacity price ($/kW-month)$0.15$0.32

(a)The reduction in owned capacity is due to the shutdown of the 811 MW Palisades plant in May 2022.
(b)The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the second quarters 2022 and 2021.


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Management's Financial Discussion and Analysis
Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $691 million for the second quarter 2021 to $726 million for the second quarter 2022 primarily due to:

•an increase of $10 million in power delivery expenses primarily due to higher reliability costs and higher safety and training costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;
•an increase of $6 million in energy efficiency expenses due to the timing of recovery from customers and higher energy efficiency costs;
•an increase of $5 million in customer service center support costs primarily due to higher contract costs;
•an increase of $5 million in bad debt expense primarily due to the deferral in 2021 of bad debt expense 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; and
•an increase of $2 million in loss provisions.

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.

Other regulatory charges (credits) - net includes:

•a regulatory charge of $224 million, recorded by Entergy Louisiana in second quarter 2022, to reflect its obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued in the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the financial statements herein for discussion of the storm cost securitization;
•a regulatory charge of $551 million, recorded by System Energy in second quarter 2022, to reflect the effects of the partial settlement agreement and offer of settlement related to pending proceedings before the FERC. See Note 2 to the financial statements herein for discussion of the partial settlement agreement and offer of settlement; and
•regulatory credits of $20 million, recorded in 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 in the Form 10-K for discussion of the 2021 formula rate plan filing.

In addition, Entergy records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and nuclear decommissioning trust earnings plus asset retirement obligation related costs collected in revenue.

Other income decreased primarily due to a $32 million charge at Entergy Louisiana for the LURC’s 1% beneficial interest in the storm trust established as part of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization. This decrease was partially offset by:

•an increase of $11 million in intercompany dividend income resulting from the Entergy Louisiana storm trust’s investment of securitization proceeds in affiliated preferred membership interests, partially offset by the liquidation of Entergy Louisiana’s investment in affiliated preferred membership interests acquired in connection with previous securitizations of storm restoration costs;
•a decrease of $8 million in non-service pension costs; and

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•an increase of $6 million due to the recognition of storm restoration carrying costs, primarily related to Hurricane Ida.

See Note 2 to the financial statements herein for discussion of the securitization.

Interest expense increased primarily due to:

•the issuance by Entergy Arkansas of $200 million of 4.20% Series mortgage bonds in March 2022;
•the issuance by Entergy Louisiana of $1 billion of 0.95% Series mortgage bonds in October 2021;
•the $1.2 billion unsecured term loan proceeds received by Entergy Louisiana in January 2022;
•the issuance by Entergy Mississippi of $200 million of 2.55% Series mortgage bonds in November 2021; and
•the issuances by Entergy New Orleans of $90 million of 4.19% Series mortgage bonds and $70 million of 4.51% Series mortgage bonds, each in November 2021.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $83 million for the second quarter 2021 to $42 million for the second quarter 2022 primarily due to a decrease of $44 million resulting from the absence of expenses from Indian Point 3, after it was shut down in April 2021, and Palisades, after it was shut down in May 2022. The decrease was partially offset by an increase of $5 million in severance and retention expenses. Severance and retention expense was a $1 million credit in the second quarter 2022 as compared to a $6 million credit in the second quarter 2021, with the credits related to revisions of the estimated remaining severance and retention costs upon the sales of Palisades and 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 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 (credits) for the second quarter 2022 include a gain of $166 million ($130 million net-of-tax) as a result of the sale of the Palisades plant in June 2022. Asset write-offs, impairments, and related charges (credits) for the second quarter 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 Palisades plant. See Note 14 to the financial statements in the Form 10-K 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 plants in the Entergy Wholesale Commodities merchant nuclear fleet.

Depreciation and amortization expenses decreased primarily due to the absence of depreciation expense from Palisades, after it was shut down in May 2022, and Indian Point 3, after it was shut down in April 2021.

Other income decreased primarily due to losses on Palisades decommissioning trust fund investments in the second quarter 2022 compared to the second quarter 2021 and the absence of earnings from the nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021, 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 Palisades plant. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Indian Point Energy Center. See Note 6 to the financial statements herein for a discussion of pension and other postretirement benefits costs.


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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 in the Form 10-K for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was 183.8% for the second quarter 2022. The difference in the effective income tax rate for the second quarter 2022 versus the federal statutory rate of 21% was primarily due to the reduction in income tax expense as a result of the securitization of Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida storm costs pursuant to Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. The high effective income tax rate was also driven by a loss before income taxes for the second quarter 2022 primarily caused by the regulatory charge recorded by System Energy as a result of the partial settlement agreement and offer of settlement. See Notes 2 and 10 to the financial statements herein for further discussion of the Entergy Louisiana securitization. See Note 2 to the financial statements herein for discussion of the System Energy settlement agreement.

The effective income tax rate was 93% for the second quarter 2021. The difference in the effective income tax rate for the second quarter 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, a reduction of a valuation allowance, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See 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 valuation allowance reduction.


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Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the six months ended June 30, 2022 to the six months ended June 30, 2021 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)
2021 Net Income (Loss) Attributable to Entergy Corporation$682,470 ($237,619)($116,260)$328,591 
Operating revenues764,425 (158,163)(47)606,215 
Fuel, fuel-related expenses, and gas purchased for resale179,494 12,153 7 191,654 
Purchased power204,383 3,770 (7)208,146 
Other regulatory charges (credits) - net755,497 — — 755,497 
Other operation and maintenance60,656 (98,570)6,539 (31,375)
Asset write-offs, impairments, and related charges (credits)— (508,686)— (508,686)
Taxes other than income taxes39,911 (170)38 39,779 
Depreciation and amortization64,013 (15,392)(954)47,667 
Other income (deductions)(51,580)(106,607)(12,480)(170,667)
Interest expense26,062 (5,315)14,390 35,137 
Other expenses1,101 (68,555)— (67,454)
Income taxes(427,440)84,224 2,545 (340,671)
Preferred dividend requirements of subsidiaries and noncontrolling interest(1,563)1 (96)(1,658)
2022 Net Income (Loss) Attributable to Entergy Corporation$493,201 $94,151 ($151,249)$436,103 

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

Results of operations for the six months ended June 30, 2022 include: 1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued as part of the securitization regulatory proceeding; and 3) a gain of $166 million ($130 million net-of-tax) as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements herein for further discussion of the System Energy partial settlement agreement and offer of settlement. See Notes 2 and 10 to the financial statements herein for further discussion of the securitization. See Note 14 to the financial statements herein for further discussion of the sale of the Palisades plant.

Results of operations for the six months ended June 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 in the Form 10-K for further discussion of the sale of Indian Point Energy Center.


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Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$5,270 
Fuel, rider, and other revenues that do not significantly affect net income409 
Retail electric price149 
Volume/weather126 
Storm restoration carrying costs59 
Return of unprotected excess accumulated deferred income taxes to customers21 
2022 operating revenues$6,034 

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:

•increases in Entergy Arkansas’s formula rate plan rates effective May 2021 and January 2022;
•an increase in Entergy Louisiana’s formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective September 2021;
•increases in Entergy Mississippi’s formula rate plan rates effective April 2021, July 2021, and April 2022;
•an increase in Entergy New Orleans’s formula rate plan rates effective November 2021; and
•increases in the transmission cost recovery factor rider effective March 2021 and March 2022, an increase in the distribution cost recovery factor rider effective January 2022, and an increase in the generation cost recovery rider effective in late January 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 3,055 GWh, or 5%, in electricity usage across all customer classes, including the effect of more favorable weather on residential and commercial sales. The increase in industrial usage was due to an increase in demand from cogeneration customers, an increase in demand from expansion projects, primarily in the chemicals, transportation, and petroleum refining industries, an increase in demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns, and an increase in demand from small industrial customers. The increase in weather-adjusted commercial usage was primarily due to an increase in customers and the effect of the COVID-19 pandemic on businesses in 2021. The increased usage from these industrial and commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

Storm restoration carrying costs, representing the equity component of storm restoration carrying costs, includes $37 million at Entergy Louisiana and $22 million at Entergy Texas, recorded in second quarter 2022,

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recognized as part of the Entergy Louisiana storm cost securitization in May 2022 and the Entergy Texas storm cost securitization in April 2022. See Note 2 to the financial statements herein for discussion of storm cost securitizations.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In the six months ended June 30, 2022, $33 million was returned to customers through reductions in operating revenues as compared to $54 million in the six months ended June 30, 2021. 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.

Total electric energy sales for Utility for the six months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential17,946 17,150 5 
Commercial13,474 12,842 5 
Industrial25,976 24,378 7 
Governmental1,226 1,197 2 
Total retail58,622 55,567 5 
Sales for resale7,562 9,016 (16)
Total66,184 64,583 2 

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 $397 million for the six months ended June 30, 2021 to $239 million for the six months ended June 30, 2022 primarily due to the shutdown of Indian Point 3 in April 2021 and Palisades in May 2022.

Following are key performance measures for Entergy Wholesale Commodities for the six months ended June 30, 2022 and 2021:
20222021
Owned capacity (MW) (a)3941,205
GWh billed3,5957,099
Entergy Wholesale Commodities Nuclear Fleet (b)
Capacity factor93%97%
GWh billed2,7416,344
Average energy price ($/MWh)$48.99$50.70
Average capacity price ($/kW-month)$0.15$0.26

(a)The reduction in owned capacity is due to the shutdown of the 811 MW Palisades plant in May 2022.
(b)The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the six months ended June 30, 2022 and 2021.

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Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,294 million for the six months ended June 30, 2021 to $1,354 million for the six months ended June 30, 2022 primarily due to:

•an increase of $18 million in power delivery expenses primarily due to higher reliability costs and higher safety and training costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;
•an increase of $11 million in customer service center support costs primarily due to higher contract costs;
•an increase of $6 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to prior year, partially offset by lower spending in 2022 on sanitation and social distancing protocols as a result of the COVID-19 pandemic;
•an increase of $5 million in legal expenses primarily due to an increase in legal and regulatory activity increasing the use of outside legal services;
•an increase of $4 million in non-nuclear generation expenses primarily due to higher expenses associated with the Hardin County Peaking Facility, which was purchased in June 2021;
•an increase of $4 million in energy efficiency expenses due to the timing of recovery from customers and higher energy efficiency costs;
•an increase of $4 million in loss provisions; and
•several individually insignificant items.

The increase was partially offset by a decrease of $5 million in insurance expenses primarily due to higher nuclear insurance refunds received in 2022, partially offset by higher premium costs.

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

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

Other regulatory charges (credits) - net includes:

•the reversal in first quarter 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 in the Form 10-K for discussion of the 2020 formula rate plan filing;
•a regulatory charge of $224 million, recorded by Entergy Louisiana in second quarter 2022, to reflect its obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued in the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the financial statements herein for discussion of the storm cost securitization; and
•a regulatory charge of $551 million, recorded by System Energy in second quarter 2022, to reflect the effects of the partial settlement agreement and offer of settlement related to pending proceedings before the FERC. See Note 2 to the financial statements herein for discussion of the partial settlement agreement and offer of settlement.

In addition, Entergy records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and nuclear decommissioning trust earnings plus asset retirement obligation related costs collected in revenue.


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Other income decreased primarily due to:

•changes in decommissioning trust fund activity, including portfolio rebalancing of the decommissioning trust funds in 2022 and 2021; and
•a $32 million charge at Entergy Louisiana for the LURC’s 1% beneficial interest in the storm trust established as part of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization.

This decrease was partially offset by:

•an increase of $11 million in intercompany dividend income resulting from the Entergy Louisiana storm trust’s investment of securitization proceeds in affiliated preferred membership interests, partially offset by the liquidation of Entergy Louisiana’s investment in affiliated preferred membership interests acquired in connection with previous securitizations of storm restoration costs;
•an increase of $11 million due to the recognition of storm restoration carrying costs, primarily related to Hurricane Ida; and
•a decrease of $8 million in non-service pension costs.

See Note 2 to the financial statements herein for discussion of the securitization.

Interest expense increased primarily due to:

•the issuance by Entergy Arkansas of $400 million of 3.35% Series mortgage bonds in March 2021;
•the issuance by Entergy Arkansas of $200 million of 4.20% Series mortgage bonds in March 2022;
•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 Louisiana of $1 billion of 0.95% Series mortgage bonds in October 2021;
•the $1.2 billion unsecured term loan proceeds received by Entergy Louisiana in January 2022;
•the issuance by Entergy Mississippi of $200 million of 3.50% Series mortgage bonds in March 2021;
•the issuance by Entergy Mississippi of $200 million of 2.55% Series mortgage bonds in November 2021; and
•the issuances by Entergy New Orleans of $90 million of 4.19% Series mortgage bonds and $70 million of 4.51% Series mortgage bonds, each in November 2021.

The increase was partially offset by the repayment by Entergy Arkansas of $350 million of 3.75% Series mortgage bonds in February 2021 and 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 $182 million for the six months ended June 30, 2021 to $84 million for the six months ended June 30, 2022 primarily due to a decrease of $87 million resulting from the absence of expenses from Indian Point 3, after it was shut down in April 2021, and Palisades, after it was shut down in May 2022, and a decrease of $5 million in severance and retention expenses. Severance and retention expenses were incurred in 2022 and 2021 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 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 (credits) for the six months ended June 30, 2022 include a gain of $166 million ($130 million net-of-tax) as a result of the sale of the Palisades plant in June 2022. Asset

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write-offs, impairments, and related charges (credits) for the six months ended June 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 Palisades plant. See Note 14 to the financial statements in the Form 10-K 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 plants in the Entergy Wholesale Commodities merchant nuclear fleet.

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, and Palisades, after it was shut down in May 2022. The decrease was partially offset by 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 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

Other income decreased primarily due to the absence of earnings from the nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021 and losses on Palisades decommissioning trust fund investments in the six months ended June 30, 2022 compared to the six months ended June 30, 2021, 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 in the Form 10-K for further discussion of the sale of the Indian Point Energy Center. See Note 6 to the financial statements herein for a 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 in the Form 10-K for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was (194.8%) for the six months ended June 30, 2022. The difference in the effective income tax rate for the six months ended June 30, 2022 versus the federal statutory rate of 21% was primarily due to the reduction in income tax expense as a result of the securitization of Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida storm costs pursuant to Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021, 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. See Notes 2 and 10 to the financial statements herein for further discussion of the Entergy Louisiana securitization.

The effective income tax rate was 12.3% for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, a reduction of a valuation allowance, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See 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 valuation allowance reduction.

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

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strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant nuclear fleet.  Following are updates to that discussion.

In April 2022, Entergy and Nebraska Public Power District signed an agreement to mutually terminate the management support services contract, under which Entergy provided plant operation support services for the 800 MW Cooper Nuclear Station located near Brownville, Nebraska, effective July 31, 2022.

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. Palisades was shut down in May 2022 and defueled in June 2022. The transaction closed in June 2022. The sale included the transfer of the nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter of 2022. See Note 14 to the financial statements herein for further discussion of the sale of the Palisades plant. 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. In February 2021 several parties, including the Michigan Attorney General, filed with the NRC petitions to intervene and requests for hearing challenging the license transfer application, and these petitions and requests for hearing remained pending with the NRC at the time of the closing of the Palisades transaction. In July 2022 the NRC issued an order granting the Michigan Attorney General’s petition hearing request.

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.

Capital Structure and Resources

Entergy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy as of June 30, 2022 is primarily due to the net retirement of debt in 2022.
June 30,
2022		December 31,
2021
Debt to capital69.1 %69.5 %
Effect of excluding securitization bonds(0.3 %)(0.1 %)
Debt to capital, excluding securitization bonds (a)68.8 %69.4 %
Effect of subtracting cash(0.4 %)(0.3 %)
Net debt to net capital, excluding securitization bonds (a)68.4 %69.1 %

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

As of June 30, 2022, 20.6% of the debt outstanding is at the parent company, Entergy Corporation, 78.9% 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

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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 2027.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the six months ended June 30, 2022 was 1.96% on the drawn portion of the facility. As of June 30, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$150$3$3,347
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.  Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit 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 Utility operating companies’ credit facilities.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of June 30, 2022, Entergy Corporation had $1.398 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2022 was 0.91%.

Entergy Louisiana had $290 million and Entergy Mississippi had $33 million in their storm reserve escrow accounts at June 30, 2022.

In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. A City Council decision is expected in third quarter 2022.

Equity Issuances and Equity Distribution Program

As discussed in the Form 10-K, 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 also enter into forward sale agreements for the sale of its common stock. Initially, the aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement could not exceed an aggregate gross sales price of $1 billion. In May 2022, Entergy increased by $1 billion the aggregate gross sales price authorized under the at the market equity distribution program. Through June 30, 2022, Entergy has utilized the equity distribution program either to sell or to enter into forward sale agreements with respect to shares of common stock with an aggregate gross sales price of approximately $880 million, of which approximately $680 million of aggregate gross sales price is the subject of forward sale agreements that have not been settled and is subject to adjustment pursuant to the forward sale

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agreements. In addition to settlement of existing forward sale agreements, Entergy Corporation currently expects to issue approximately $320 million of equity through 2024. See Note 3 to the financial statements herein for discussion of the forward sale agreements and common stock issuances and sales under the equity distribution program.

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida (Entergy Louisiana)

As discussed in the Form 10-K, 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 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 additional outages.

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 for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were 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 sought an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana requested that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was 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 August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage 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, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, Entergy Louisiana reclassified $1.942 billion from utility plant to other regulatory assets.

In May 2022 the securitization financing closed, resulting in the issuance of $3.194 billion principal amount of bonds by Louisiana Local Government Environmental Facilities and Community Development Authority

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(LCDA), a political subdivision of the State of Louisiana. The securitization was authorized pursuant to the Louisiana Utilities Restoration Corporation Act, Part VIII of Chapter 9 of Title 45 of the Louisiana Revised Statutes, as supplemented by Act 293 of the Louisiana legislature approved in 2021. The LCDA loaned the proceeds to the LURC. Pursuant to Act 293, the LURC contributed the net bond proceeds to a State legislatively authorized and LURC-sponsored trust, Restoration Law Trust I (the storm trust).

Pursuant to Act 293, the net proceeds of the bonds were used by the storm trust to purchase 31,635,718.7221 Class A preferred, non-voting membership interest units (the preferred interests) issued by Entergy Finance Company, LLC, a majority-owned indirect subsidiary of Entergy. Entergy Finance Company is required to make annual distributions (dividends) commencing on December 15, 2022 on the preferred interests issued to the storm trust. These annual dividends received by the storm trust will be distributed to Entergy Louisiana and the LURC, as beneficiaries of the storm trust. Specifically, 1% of the annual dividends received by the storm trust will be distributed to the LURC, for the benefit of customers, and 99% will be distributed to Entergy Louisiana, net of storm trust expenses. The preferred interests have a stated annual cumulative cash dividend rate of 7% and a liquidation price of $100 per unit. The terms of the preferred interests include certain financial covenants to which Entergy Finance Company is subject.

Entergy and Entergy Louisiana do not report the bonds issued by the LCDA on their balance sheets because the bonds are the obligation of the LCDA. The bonds are secured by system restoration property, which is the right granted by law to the LURC to collect a system restoration charge from customers. The system restoration charge is adjusted at least semi-annually to ensure that it is sufficient to service the bonds. Entergy Louisiana collects the system restoration charge on behalf of the LURC and remits the collections to the bond indenture trustee. Entergy Louisiana began collecting the system restoration charge effective with the first billing cycle of June 2022 and the system restoration charge is expected to remain in place up to 15 years. Entergy and Entergy Louisiana do not report the collections as revenue because Entergy Louisiana is merely acting as a billing and collection agent for the LCDA and the LURC. In the remote possibility that the system restoration charge, as well as any funds in the excess subaccount and funds in the debt service reserve account, are insufficient to service the bonds resulting in a payment default, the storm trust is required to liquidate Entergy Finance Company preferred interests in an amount equal to what would be required to cure the default. The estimated value of this indirect guarantee is immaterial.

From the proceeds from the issuance of the preferred membership interests, Entergy Finance Company distributed $1.4 billion to its parent, Entergy Holdings Company, LLC. Subsequently, Entergy Holdings Company liquidated, distributing the $1.4 billion it received from Entergy Finance Company to Entergy Louisiana as holder of 6,843,780.24 units of Class A, 4,126,940.15 units of Class B, and 2,935,152.69 units of Class C preferred membership interests. Entergy Louisiana had acquired these preferred membership interests with proceeds from previous securitizations of storm restoration costs. Entergy Finance Company loaned the remaining $1.7 billion from the preferred membership interests proceeds to Entergy which used the cash to redeem $650 million of 4.00% Series senior notes due July 2022 and indirectly contributed $1 billion to Entergy Louisiana as a capital contribution.

Entergy Louisiana used the $1 billion capital contribution to fund its Hurricane Ida escrow account and subsequently withdrew the $1 billion from the escrow account. With a portion of the $1 billion withdrawn from the escrow account and the $1.4 billion from the Entergy Holdings Company liquidation, Entergy Louisiana deposited $290 million in a restricted escrow account as a storm damage reserve for future storms, used $1.2 billion to repay its unsecured term loan due June 2023, and used $435 million to redeem a portion of its 0.62% Series mortgage bonds due November 2023.

As discussed in Note 10 to the financial statements herein, the securitization resulted in recognition of a reduction of income tax expense of approximately $290 million by Entergy Louisiana. Entergy’s recognition of reduced income tax expense was offset by other tax charges resulting in a net reduction of income tax expense of $283 million. In recognition of obligations related to an LPSC ancillary order issued as part of the securitization

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regulatory proceeding, Entergy Louisiana recorded a $224 million ($165 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to share the benefits of the securitization with customers.

As discussed in Note 12 to the financial statements herein, Entergy Louisiana consolidates the storm trust as a variable interest entity and the LURC’s 1% beneficial interest is shown as noncontrolling interest in the financial statements. In second quarter 2022, Entergy Louisiana recorded a charge of $31.6 million in other income to reflect the LURC’s beneficial interest in the trust.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs of $57 million through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow account from which funds were withdrawn to finance costs associated with Hurricane Ida restoration. In June 2022, 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. A procedural schedule has been established with a hearing in December 2022.

Hurricane Ida (Entergy New Orleans)

As discussed in the Form 10-K, 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 damage to distribution and transmission infrastructure, including the loss of connectivity to the eastern interconnection. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. In June 2022, Entergy New Orleans filed an application with the City Council requesting approval and certification that storm restoration costs associated with Hurricane Ida of approximately $170 million were reasonable, necessary, and prudently incurred to enable Entergy New Orleans to restore electric service to its customers and to repair Entergy New Orleans’s electric utility infrastructure. Carrying costs through December 2022 related to Hurricane Ida restoration costs were $9 million. Additionally, Entergy New Orleans is requesting approval that the $39 million withdrawal from its funded storm reserve in September 2021 and $7 million in excess storm reserve escrow withdrawals related to Hurricane Zeta and prior miscellaneous storms are properly applied to Hurricane Ida storm restoration costs, the application of which reduces the amount to be recovered from Entergy New Orleans customers by $46 million. The City Council has not yet set a procedural schedule regarding the requested relief, though Entergy New Orleans requested resolution by the end of first quarter 2023. Entergy New Orleans intends to file with the City Council an application proposing a financing method for recovery of costs deemed eligible for recovery.

Hurricane Laura, Hurricane Delta, and Winter Storm Uri (Entergy Texas)

As discussed in the Form 10-K, 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 July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system

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restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

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 2022 through 2024. Following are updates to that discussion.

Following are the current annual amounts of Entergy’s planned construction and other capital investments.

Planned construction and capital investments202220232024
 (In Millions)
Utility:   
Generation$1,080 $1,325 $2,320 
Transmission835 805 1,025 
Distribution1,360 1,520 1,740 
Utility Support590 440 315 
Total3,865 4,090 5,400 
Entergy Wholesale Commodities and Other10 — — 
Total$3,875 $4,090 $5,400 

The updated capital plan for 2022-2024 reflects incremental capital investments for potential generation projects, accelerated resilience spending, and increased capital project costs. The capital plan includes investments in generation projects to modernize, decarbonize, and diversify Entergy’s portfolio, including Sunflower Solar, West Memphis Solar, Driver Solar, Orange County Advanced Power Station, and St. Jacques Louisiana Solar; investments in Entergy’s nuclear fleet; transmission spending to drive reliability and resilience while also supporting renewables expansion; distribution and Utility support spending to improve reliability, resilience, and customer experience through projects focused on asset renewals and enhancements and grid stability.

While Entergy is still assessing the effect on its planned solar projects, the investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has exacerbated previously existing supply chain disruptions, which have negatively affected the timing and cost of completion of these projects.


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Walnut Bend Solar

As discussed in the Form 10-K, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In January 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Closing was expected to occur in 2022. The counter-party has notified Entergy Arkansas that it is terminating the project, though it is willing to consider an alternative for the site. Entergy Arkansas has disputed the right of termination. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2022.

West Memphis Solar

As discussed in the Form 10-K, in October 2021 the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In April 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Entergy Arkansas views the progress of the outreach to potential tax equity investors and the current status of the discussions as consistent with its expectations for the timeline for achieving a tax equity partnership. Closing had been expected to occur in 2023. The counter-party has notified Entergy Arkansas that it is seeking changes to certain terms of the build-own-transfer agreement, including both cost and schedule. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2023.

Driver Solar

In April 2022, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 250 MW Driver Solar facility is in the public interest and requested cost recovery through the formula rate plan rider. The acquisition of Driver Solar will be contingent upon receiving all necessary regulatory and Board approvals. The APSC established a procedural schedule with a hearing scheduled in June 2022, but the parties later agreed to waive the hearing and submit the matter to the APSC for a decision consistent with the filed record. The facility is expected to be in service by the end of 2024. Negotiations with the counter-party are expected to conclude in August 2022, and Entergy Arkansas has requested an APSC decision by August 31, 2022.

2021 Solar Certification and the Geaux Green Option

As discussed in the Form 10-K, in November 2021, Entergy Louisiana filed an application with the LPSC seeking certification of and approval for the addition of four new solar photovoltaic resources with a combined nameplate capacity of 475 megawatts (the 2021 Solar Portfolio) and the implementation of a new green tariff, the Geaux Green Option (Rider GGO). The LPSC has established a procedural schedule that is expected to result in an LPSC decision by the end of 2022. In March 2022 direct testimony from Walmart, the Louisiana Energy Users Group (LEUG) and the LPSC staff was filed. Each party recommended that the LPSC approve the resources proposed in Entergy Louisiana’s application, and the LPSC staff witness indicated that the process through which Entergy Louisiana solicited or obtained the proposals for the resources complies with applicable LPSC orders. LPSC staff and LEUG’s witnesses made recommendations to modify the proposed Rider GGO and Entergy Louisiana’s proposed rate relief. In April 2022, LPSC staff and LEUG filed cross-answering testimony concerning the other party’s proposed modifications to Rider GGO and the proposed rate recovery. Entergy Louisiana filed rebuttal testimony in June 2022. Settlement talks are ongoing, and a hearing is set for mid-August 2022.

Sunflower Solar

As discussed in the Form 10-K, 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. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax

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equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. In July 2022, pursuant to the MPSC’s April 2020 order, Entergy Mississippi submitted a compliance filing to the MPSC with updated calculations of the impact of the Sunflower Solar facility on rate base and revenue requirement for the Sunflower Solar facility and benefits of the tax equity partnership. A final payment will be made upon substantial completion of the facility and is currently expected in third quarter 2022. See Note 14 to the financial statements herein for discussion of Entergy Mississippi’s purchase of the Sunflower Solar facility.

Orange County Advanced Power Station

As discussed in the Form 10-K, 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 initially-estimated expected total cost of $1.2 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. In December 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2022 certain intervenors filed testimony opposing the hydrogen co-firing component of the proposed project and others filed testimony opposing the project outright. Also in March 2022, PUCT staff filed testimony opposing the hydrogen co-firing component of the proposed project, but otherwise taking no specific position on the merits of the project. The PUCT staff also proposed that the PUCT establish a maximum amount that Entergy Texas may recover in rates attributable to the project. In April 2022, Entergy Texas filed rebuttal testimony addressing and rebutting these various arguments. Also in April 2022 the ALJs with the State Office of Administrative Hearings approved a continuance of the hearing on the merits from April 2022 to June 2022, providing Entergy Texas an opportunity to accelerate the determination and fixing of pricing for 60 days for the Orange County Advanced Power Station prior to the hearing. In May 2022, Entergy Texas obtained and provided to the parties an updated fixed pricing option of $1.58 billion, available until mid-July 2022. The hearing on the merits was held in June 2022 and post-hearing briefs were submitted in July 2022. The initial fixed pricing window closed in July 2022, and Entergy Texas intends to obtain a new fixed pricing option prior to PUCT approval and issuance of notice to proceed. A final order by the PUCT is expected in the fourth quarter of 2022. Entergy Texas also is pursuing environmental permitting that is required prior to the commencement of construction. Subject to receipt of required regulatory approvals, permits, and other conditions, the facility is expected to be in service by the end of 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 July 2022 meeting, the Board declared a dividend of $1.01 per share, which is the same quarterly dividend per share that Entergy has paid since the third quarter 2021.


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Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Millions)
Cash and cash equivalents at beginning of period$443 $1,759 
Net cash provided by (used in):  
Operating activities816 747 
Investing activities(3,224)(2,826)
Financing activities2,545 1,007 
Net increase (decrease) in cash and cash equivalents137 (1,072)
Cash and cash equivalents at end of period$580 $687 

Operating Activities

Net cash flow provided by operating activities increased $69 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•higher collections from Utility customers;
•a decrease of $119 million in pension contributions in 2022 as compared to prior period. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” herein and in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding;
•$119 million in severance and retention payments in 2021. 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 Power Business” above for a discussion of the exit of the Entergy Wholesale Commodities merchant power business;
•an increase of $43 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
•income tax refunds of $7 million in 2022 compared to income tax payments of $27 million in 2021. Entergy had income tax refunds in 2022 as a result of an overpayment on a prior year state income tax return. 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.

The increase was partially offset by:

•increased fuel costs. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;
•lower Entergy Wholesale Commodities revenues in 2022; and
•an increase of approximately $70 million in storm spending primarily due to spending on Hurricane Ida in 2022, offset with decreased spending on Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for discussion of storm restoration efforts.


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Investing Activities

Net cash flow used in investing activities increased $398 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•an increase of $334 million in net payments to storm reserve escrow accounts;
•the initial payment of approximately $105 million in May 2022 for the purchase of the Sunflower Solar facility by the Entergy Mississippi tax equity partnership. See Note 14 to the financial statements herein for further discussion of the Sunflower Solar facility purchase;
•an increase of $101 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2022;
•a decrease of $55 million in decommissioning trust fund investment activity;
•an increase of $43 million in information technology capital expenditures primarily due to increased spending on various technology projects in 2022;
•an increase of $41 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; and
•cash collateral of $30 million posted in 2022 to support Entergy Texas’s obligations to MISO.

The increase was partially offset by a decrease of $273 million in transmission construction expenditures primarily due to lower capital expenditures for storm restoration in 2022 and the purchase of the Hardin County Peaking Facility by Entergy Texas in June 2021 for approximately $37 million.

Financing Activities

Net cash flow provided by financing activities increased $1,538 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to proceeds from securitization of $3,164 million received by the storm trust at Entergy Louisiana in 2022 and an increase of $958 million in net issuances of commercial paper in 2022 compared to 2021. The increase was partially offset by long-term debt activity using approximately $442 million of cash in 2022 compared to providing approximately $2,108 million of cash in 2021. See Note 2 to the financial statements herein for a discussion of the Entergy Louisiana securitization. For details of Entergy’s commercial paper program and long-term debt, see Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K.

Rate, Cost-recovery, and Other Regulation

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

State and Local Rate Regulation and Fuel-Cost Recovery

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

Federal Regulation

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


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Market and Credit Risk Sensitive Instruments

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 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 June 30, 2022, based on power prices at that time, Entergy had liquidity exposure of $24 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $12 million of posted cash collateral.

Nuclear Matters

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

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. Following is an update to that discussion.

Qualified Pension and Other Postretirement Benefits

As discussed in the Form 10-K, Entergy sponsors qualified, defined benefit pension plans, including cash balance plans and final average pay plans. Entergy’s reported costs of providing these benefits, as described in Note 11 to the financial statements in the Form 10-K, are affected by numerous factors. Key actuarial assumptions utilized in determining qualified pension and other postretirement health care and life insurance costs include the expected long-term rate of return on plan assets. For 2022, Entergy assumed a long-term rate of return on its qualified pension plan assets of 6.75%. Through June 30, 2022, due to the decline in the equity markets, Entergy experienced a 18% loss on its qualified pension plan assets, which have declined in fair value from $7 billion at December 31, 2021 to $5.4 billion at June 30, 2022.

As described more fully in the Form 10-K, in accordance with pension accounting standards, Entergy utilizes a number of accounting mechanisms that reduce the volatility of reported pension costs. Differences between actuarial assumptions and actual plan results are deferred and are amortized into expense when the accumulated differences exceed 10% of the greater of the projected benefit obligation or the market-related value of plan assets. The excess is amortized over the average remaining service period of active employees or the average remaining life expectancy of plan participants if almost all are inactive, as in the case of certain qualified pension plans in which some companies within the Entergy Wholesale Commodities segment participate. Also, with regard to pension and other postretirement costs, Entergy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the market-related value (MRV) of plan assets. In general, Entergy determines the MRV of its pension plan assets by calculating a value that uses a 20-quarter phase-in of the difference between actual and expected returns and for its other postretirement benefit plan assets Entergy generally uses fair value.

Minimum required funding calculations as determined under Pension Protection Act guidance, as amended by the American Rescue Plan Act of 2021, are performed annually as of January 1 of each year and are based on measurements of the assets and funding liabilities as measured at that date, and Entergy’s expected contributions for

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2022 are reported in Note 6 to the financial statements herein. Any excess of the funding liability over the calculated fair market value of assets results in a funding shortfall that, under the Pension Protection Act, must be funded over a fifteen-year rolling period. The Pension Protection Act also imposes certain plan limitations if the funded percentage, which is based on calculated fair market values of assets divided by funding liabilities, does not meet certain thresholds. For funding purposes, asset gains and losses are smoothed in to the calculated fair market value of assets. The funding liability is based upon a weighted average 24-month corporate bond rate published by the U.S. Treasury which is generally subject to a corridor of the 25-year average of prior segment rates. Periodic changes in asset returns and interest rates can affect funding shortfalls and future cash contributions.

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 STATEMENTS OF OPERATIONS
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands, Except Share Data)
OPERATING REVENUES
Electric$3,258,255 $2,641,375 $5,914,031 $5,179,794 
Natural gas48,008 31,998 120,369 90,166 
Competitive businesses88,933 148,697 238,722 396,947 
TOTAL3,395,196 2,822,070 6,273,122 5,666,907 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale651,946 626,064 1,318,885 1,127,231 
Purchased power570,627 252,371 840,251 632,105 
Nuclear refueling outage expenses36,917 43,700 79,918 87,438 
Other operation and maintenance777,715 781,118 1,456,529 1,487,904 
Asset write-offs, impairments, and related charges (credits)(164,066)342,092 (163,321)345,365 
Decommissioning62,859 86,199 124,907 184,841 
Taxes other than income taxes172,244 155,911 352,392 312,613 
Depreciation and amortization444,759 421,545 883,731 836,064 
Other regulatory charges (credits) - net761,063 (55,138)732,638 (22,859)
TOTAL3,314,064 2,653,862 5,625,930 4,990,702 
OPERATING INCOME 81,132 168,208 647,192 676,205 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction13,568 16,873 29,440 31,449 
Interest and investment income (loss)(99,049)71,329 (120,968)214,645 
Miscellaneous - net35,578 (62,844)43,182 (123,773)
TOTAL(49,903)25,358 (48,346)122,321 
INTEREST EXPENSE
Interest expense231,613 220,340 459,235 426,226 
Allowance for borrowed funds used during construction(4,752)(6,964)(10,848)(12,976)
TOTAL226,861 213,376 448,387 413,250 
INCOME (LOSS) BEFORE INCOME TAXES(195,632)(19,810)150,459 385,276 
Income taxes(359,643)(18,416)(293,145)47,526 
CONSOLIDATED NET INCOME (LOSS)164,011 (1,394)443,604 337,750 
Preferred dividend requirements of subsidiaries and noncontrolling interest4,308 4,580 7,501 9,159 
NET INCOME (LOSS) ATTRIBUTABLE TO ENTERGY CORPORATION
$159,703 ($5,974)$436,103 $328,591 
Earnings (loss) per average common share:
Basic$0.79 ($0.03)$2.15 $1.64 
Diluted$0.78 ($0.03)$2.13 $1.63 
Basic average number of common shares outstanding203,383,199 200,775,395 203,164,628 200,651,162 
Diluted average number of common shares outstanding204,712,242 200,775,395 204,291,597 201,352,830 
See Notes to Financial Statements.



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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)
Net Income (Loss)$164,011 ($1,394)$443,604 $337,750 
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax benefit of $—, $66, $—, and $7,935)
24 (222)48 (29,802)
Pension and other postretirement liabilities (net of tax expense of $1,642, $6,231, $4,184, and $12,545)
6,045 22,098 14,373 45,065 
Net unrealized investment gain (loss) (net of tax expense (benefit) of $3,768, ($27), ($3,453), and ($25,608))
6,471 (108)(5,931)(44,795)
Other comprehensive income (loss)12,540 21,768 8,490 (29,532)
Comprehensive Income 176,551 20,374 452,094 308,218 
Preferred dividend requirements of subsidiaries and noncontrolling interest4,308 4,580 7,501 9,159 
Comprehensive Income Attributable to Entergy Corporation$172,243 $15,794 $444,593 $299,059 
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Consolidated net income $443,604 $337,750 
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization1,113,954 1,150,294 
Deferred income taxes, investment tax credits, and non-current taxes accrued(274,139)115,274 
Asset write-offs, impairments, and related charges (credits)(163,321)345,339 
Changes in working capital:
Receivables(224,499)(154,277)
Fuel inventory16,381 16,718 
Accounts payable42,915 (131,414)
Taxes accrued(420)(69,711)
Interest accrued(11,947)(162)
Deferred fuel costs(667,247)(286,116)
Other working capital accounts(136,853)(86,774)
Changes in provisions for estimated losses295,987 (54,278)
Changes in other regulatory assets724,227 93,776 
Changes in other regulatory liabilities15,788 170,932 
Effect of securitization on regulatory asset(1,036,955)— 
Changes in pension and other postretirement liabilities(167,682)(259,593)
Other846,170 (441,211)
Net cash flow provided by operating activities
815,963 746,547 
INVESTING ACTIVITIES
Construction/capital expenditures(2,720,596)(2,883,376)
Allowance for equity funds used during construction29,440 31,449 
Nuclear fuel purchases(114,843)(73,858)
Payment for purchase of plant or assets(105,149)(36,534)
Net proceeds (payments) from sale of assets (7,082)22,421 
Litigation proceeds from settlement agreement9,829 — 
Changes in securitization account337 9,685 
Payments to storm reserve escrow account(1,290,314)(17)
Receipts from storm reserve escrow account1,000,218 44,205 
Decrease (increase) in other investments(36,057)10,753 
Litigation proceeds for reimbursement of spent nuclear fuel storage costs32,367 15,735 
Proceeds from nuclear decommissioning trust fund sales1,099,503 3,837,482 
Investment in nuclear decommissioning trust funds(1,121,635)(3,804,170)
Net cash flow used in investing activities(3,223,982)(2,826,225)
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt3,851,061 5,008,330 
Treasury stock26,952 4,039 
Common stock— 26,817 
Retirement of long-term debt(4,293,423)(2,900,566)
Changes in credit borrowings and commercial paper - net196,694 (761,244)
Capital contribution from noncontrolling interest9,595 — 
Proceeds from trust related to securitization3,163,572 — 
Other10,523 20,467 
Dividends paid:
Common stock(410,466)(381,224)
Preferred stock(9,159)(9,159)
Net cash flow provided by financing activities2,545,349 1,007,460 
Net increase (decrease) in cash and cash equivalents137,330 (1,072,218)
Cash and cash equivalents at beginning of period442,559 1,759,099 
Cash and cash equivalents at end of period$579,889 $686,881 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$454,666 $428,301 
Income taxes($7,485)$27,488 
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$66,265 $44,944 
Temporary cash investments513,624 397,615 
Total cash and cash equivalents579,889 442,559 
Accounts receivable:
Customer804,552 786,866 
Allowance for doubtful accounts(25,587)(68,608)
Other238,496 231,843 
Accrued unbilled revenues545,027 420,255 
Total accounts receivable1,562,488 1,370,356 
Deferred fuel costs983,935 324,394 
Fuel inventory - at average cost138,194 154,575 
Materials and supplies - at average cost1,094,564 1,041,515 
Deferred nuclear refueling outage costs186,682 133,422 
Prepayments and other249,659 156,774 
TOTAL4,795,411 3,623,595 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds4,090,109 5,514,016 
Non-utility property - at cost (less accumulated depreciation)358,609 357,576 
Other445,181 159,455 
TOTAL4,893,899 6,031,047 
PROPERTY, PLANT, AND EQUIPMENT
Electric63,209,561 64,263,250 
Natural gas672,282 658,989 
Construction work in progress1,827,581 1,511,966 
Nuclear fuel518,120 577,006 
TOTAL PROPERTY, PLANT, AND EQUIPMENT66,227,544 67,011,211 
Less - accumulated depreciation and amortization25,013,847 24,767,051 
PROPERTY, PLANT, AND EQUIPMENT - NET41,213,697 42,244,160 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $303,410 as of June 30, 2022 and $49,579 as of December 31, 2021)
5,889,029 6,613,256 
Deferred fuel costs241,052 240,953 
Goodwill377,172 377,172 
Accumulated deferred income taxes87,600 54,186 
Other329,719 269,873 
TOTAL6,924,572 7,555,440 
TOTAL ASSETS$57,827,579 $59,454,242 
See Notes to Financial Statements.

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CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$909,030 $1,039,329 
Notes payable and commercial paper1,397,871 1,201,177 
Accounts payable1,935,286 2,610,132 
Customer deposits410,307 395,184 
Taxes accrued419,408 419,828 
Interest accrued179,204 191,151 
Deferred fuel costs— 7,607 
Pension and other postretirement liabilities61,911 68,336 
Current portion of unprotected excess accumulated deferred income taxes18,935 53,385 
Other209,663 204,613 
TOTAL5,541,615 6,190,742 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued4,479,428 4,706,797 
Accumulated deferred investment tax credits207,868 211,975 
Regulatory liability for income taxes - net1,216,339 1,255,692 
Other regulatory liabilities2,733,436 2,643,845 
Decommissioning and asset retirement cost liabilities4,173,137 4,757,084 
Accumulated provisions453,109 157,122 
Pension and other postretirement liabilities1,788,068 1,949,325 
Long-term debt (includes securitization bonds of $335,995 as of June 30, 2022 and $83,639 as of December 31, 2021)
24,543,896 24,841,572 
Other652,702 815,284 
TOTAL40,247,983 41,338,696 
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund219,410 219,410 
EQUITY
Preferred stock, no par value, authorized 1,000,000 shares in 2022 and 2021; issued shares in 2022 and 2021 - none
— — 
Common stock, $.01 par value, authorized 499,000,000 shares in 2022 and 2021; issued 271,965,510 shares in 2022 and 2021
2,720 2,720 
Paid-in capital6,750,368 6,766,239 
Retained earnings10,266,189 10,240,552 
Accumulated other comprehensive loss(324,038)(332,528)
Less - treasury stock, at cost (68,548,479 shares in 2022 and 69,312,326 shares in 2021)
4,984,160 5,039,699 
Total common shareholders' equity11,711,079 11,637,284 
Subsidiaries' preferred stock without sinking fund and noncontrolling interest107,492 68,110 
TOTAL11,818,571 11,705,394 
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY$57,827,579 $59,454,242 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2022
(Unaudited)
Common Shareholders’ Equity
Subsidiaries’ Preferred Stock and Noncontrolling InterestCommon
Stock		Treasury
Stock		Paid-in
Capital		Retained EarningsAccumulated Other Comprehensive LossTotal
(In Thousands)
Balance at December 31, 2021$68,110 $2,720 ($5,039,699)$6,766,239 $10,240,552 ($332,528)$11,705,394 
Consolidated net income (a)3,193 — — — 276,400 — 279,593 
Other comprehensive loss— — — — — (4,050)(4,050)
Common stock issuances related to stock plans
— — 36,612 (31,085)— — 5,527 
Common stock dividends declared— — — — (205,058)— (205,058)
Preferred dividend requirements of subsidiaries (a)
(4,580)— — — — — (4,580)
Balance at March 31, 2022$66,723 $2,720 ($5,003,087)$6,735,154 $10,311,894 ($336,578)$11,776,826 
Consolidated net income (a)4,308 — — — 159,703 — 164,011 
Other comprehensive income— — — — — 12,540 12,540 
Common stock issuances related to stock plans— — 18,927 15,214 — — 34,141 
Common stock dividends declared— — — — (205,408)— (205,408)
Beneficial interest in storm trust31,636 — — — — — 31,636 
Capital contributions from noncontrolling interest 9,595 — — — — — 9,595 
Distributions to noncontrolling interest(190)— — — — — (190)
Preferred dividend requirements of subsidiaries (a)(4,580)— — — — — (4,580)
Balance at June 30, 2022$107,492 $2,720 ($4,984,160)$6,750,368 $10,266,189 ($324,038)$11,818,571 
See Notes to Financial Statements.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2022 and second quarter 2022 each includes $4 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.


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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2021
(Unaudited)
Common Shareholders’ Equity
Subsidiaries’ Preferred Stock and Noncontrolling InterestCommon
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 
See Notes to Financial Statements.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2021 and second quarter 2021 each includes $4 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

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

Vidalia Purchased Power Agreement

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

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

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

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. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

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.


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Notes to Financial Statements
Employment and Labor-related Proceedings

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

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.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovered balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, 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. In April 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s fuel adjustment clause charges in February 2021 that did not recommend any financial disallowances, but included several prospective recommendations. Responsive testimony was filed by one intervenor and the parties agreed to suspend any procedural schedule and move toward settlement discussions to close the matter.

In May 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s purchased gas adjustment charges in February 2021 that did not propose any financial disallowances. The LPSC staff and Entergy

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Notes to Financial Statements
Louisiana have agreed to suspend any procedural schedule and move toward settlement discussions to close the matter.

To mitigate high electric bills, primarily driven by high summer usage and elevated gas prices, Entergy Louisiana has deferred approximately $135 million of fuel expense incurred in April, May, and June 2022 (as reflected on June, July, and August 2022 bills). Deferrals from April and May 2022 are expected to be recovered in the last four months of 2022 and June 2022 deferrals will be included in the over/under calculation of the fuel adjustment clause.

Entergy Mississippi

See “Complaints Against System Energy - System Energy Settlement with the MPSC” below for discussion of the settlement agreement filed with the FERC in June 2022. The settlement, which is contingent upon FERC approval, provides for a refund of $235 million from System Energy to Entergy Mississippi. In July 2022 the MPSC directed the disbursement of settlement proceeds, ordering Entergy Mississippi to provide a one-time $80 bill credit to each of its approximately 460,000 retail customers to be effective during the September 2022 billing cycle, and to apply the remaining proceeds to Entergy Mississippi’s under-recovered deferred fuel balance.

Entergy Texas

In May 2022, Entergy Texas filed an application with the PUCT to implement an interim fuel surcharge to collect the cumulative under-recovery of approximately $51.7 million, including interest, of fuel and purchased power costs incurred from May 1, 2020 through December 31, 2021. The under-recovery balance is primarily attributable to the impacts of Winter Storm Uri, including historically high natural gas prices, partially offset by settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas proposed that the interim fuel surcharge be assessed over a period of six months beginning with the first billing cycle after the PUCT issues a final order, but no later than the first billing cycle of September 2022. Also in May 2022, the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2022, Entergy Texas filed on behalf of the parties an unopposed settlement resolving all issues in the proceeding. In addition, Entergy Texas filed on behalf of the parties a motion to admit evidence, to approve interim rates as requested in the initial application, and to remand the proceeding to the PUCT to consider the unopposed settlement. In August 2022 the ALJ with the State Office of Administrative Hearings issued an order granting Entergy Texas’s motion, approving interim rates effective with the first billing cycle of September 2022, and remanding the case to the PUCT for final approval.

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

2022 Formula Rate Plan Filing

In July 2022, Entergy Arkansas filed with the APSC its 2022 formula rate plan filing to set its formula rate for the 2023 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2023 and a netting adjustment for the historical year 2021. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2023 projected year is 7.40% resulting in a revenue deficiency of $104.8 million. The earned rate of return on common equity for the 2021 historical year was 8.38% resulting in a $15.2 million netting adjustment. The total proposed revenue change for the 2023 projected year and 2021 historical year netting adjustment is $119.9 million. By operation of the formula rate plan, Entergy Arkansas’s

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Notes to Financial Statements
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 $79.3 million.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of June 30, 2022, Entergy Arkansas had a regulatory asset of $36.6 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2021 Formula Rate Plan Filing

In May 2022, Entergy Louisiana filed its formula rate plan evaluation report for its 2021 calendar year operations. The 2021 test year evaluation report produced an earned return on common equity of 8.33%, with a base formula rate plan revenue increase of $65.3 million. Other increases in formula rate plan revenue driven by reductions in Tax Cut and Jobs Act credits and additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism are partly offset by an increase in net MISO revenues, leading to a net increase in formula rate plan revenue of $152.9 million. 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 $86 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $66.9 million. Subject to refund and LPSC review, the resulting changes will be effective for bills rendered during the first billing cycle of September 2022.

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. 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 June 30, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% 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 $48.6 million. The 2021 look-back filing compares actual

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2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022.

In June 2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2022 test year filing that resulted in a total rate increase of $48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2021 look-back filing reflected an earned return on rate base of 5.99% in calendar year 2021, which is below the look-back bandwidth, resulting in a $34.3 million increase in the formula rate plan revenues on an interim basis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective in August 2022.

In July 2022 the MPSC directed Entergy Mississippi to flow $14.1 million of the power management rider over-recovery balance to customers beginning in August 2022 through December 2022 to mitigate the bill impact of the increase in formula rate plan revenues.

Sunflower Solar

As discussed in the Form 10-K, 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. In July 2022, pursuant to the MPSC’s April 2020 order, Entergy Mississippi submitted a compliance filing to the MPSC with updated calculations of the impact of the Sunflower Solar facility on rate base and revenue requirement for the Sunflower Solar facility and benefits of the tax equity partnership. See Note 14 to the financial statements herein for discussion of Entergy Mississippi’s purchase of the Sunflower Solar facility.

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 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of June 30, 2022, Entergy Mississippi had a regulatory asset of $13.1 million for costs associated with the COVID-19 pandemic. Entergy Mississippi received approval to recover this regulatory asset through its formula rate plan rider over a three-year period beginning August 2022.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report, subsequently updated in a July 2022 filing, produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $42.1 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $34.1 million and an increase in authorized gas revenues of $3.3 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. In July 2022 the City Council’s advisors issued a report seeking a reduction to Entergy New Orleans’s proposed increase of approximately $17.1 million in total for electric and gas revenues. The parties have a 25-day period to attempt to reach an agreement on the final amount to increase revenues, with implementation of resulting rates effective with the first billing cycle of September 2022 pursuant to the formula rate plan tariff. For any disputed rate adjustments,

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however, the City Council will set a procedural schedule that will extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of June 30, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic. As part of its 2022 formula rate plan filing, Entergy New Orleans requested recovery of this regulatory asset over a five-year period beginning September 2022.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

2022 Base Rate Case

In July 2022, Entergy Texas filed a base rate case with the PUCT seeking an increase in base rates of approximately $131.4 million. The base rate case was based on a 12-month test year ending December 31, 2021. Key drivers of the requested increase are changes in depreciation rates as the result of a depreciation study and an increase in the return on equity. In addition, Entergy Texas included capital additions placed into service for the period of January 1, 2018 through December 31, 2021, including those additions currently reflected in the distribution and transmission cost recovery factor riders and the generation cost recovery rider, all of which would be reset to zero as a result of this proceeding. In July 2022, the PUCT referred the proceeding to the State Office of Administrative Hearings. Also in July 2022, the ALJ with the State Office of Administrative Hearings approved a procedural schedule with a hearing on the merits in December 2022.

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, 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. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 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, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, 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. In January 2022 the PUCT referred the proceeding to the State Office of Administrative Hearings. In February 2022 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 2022. In February 2022 the ALJ granted the motion for interim rates, admitted evidence, and remanded the case to the

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PUCT for consideration of a final order at a future open meeting. In June 2022 the PUCT issued an order approving the settlement.

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 to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

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 represented no change from the generation cost recovery rider rates 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. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility. Concurrently with filing of the unanimous settlement agreement, Entergy Texas submitted an agreed motion to admit evidence and remand the case to the PUCT for review and consideration of the settlement agreement, which motion was granted by the ALJ with the State Office of Administrative Hearings.

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. As of June 30, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic. As part of its 2022 base rate case filing, Entergy Texas requested recovery of its regulatory asset over a three-year period beginning December 2022.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the

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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 the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023. In June 2022, Entergy Arkansas filed a motion asserting that it is entitled to summary judgment because Entergy Arkansas’s position that the APSC’s order is pre-empted by the filed rate doctrine and violates the Dormant Commerce Clause is premised on facts that are not subject to genuine dispute. In July 2022, Arkansas Electric Energy Consumers, Inc., an industrial customer association, filed a motion to intervene and to hold Entergy Arkansas’s motion for summary judgment in abeyance pending a ruling on the motion to intervene. Entergy Arkansas filed a consolidated opposition to both motions.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion. See “System Energy Settlement with the MPSC” below for discussion of a partial settlement agreement and offer of settlement related to the pending proceedings before the FERC.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. 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 $61 million, which includes interest through June 30, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued.

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

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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 June 30, 2022 is approximately $422 million, plus interest, which is approximately $139 million through June 30, 2022. 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 June 30, 2022.

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.

LPSC 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.

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 expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, the APSC, and the City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect

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the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that: (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, the APSC, and the City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such

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issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, the APSC, and the City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

In April 2022, System Energy filed cross-answering testimony in response to the FERC trial staff’s recommendations of refunds for the accumulated deferred income taxes issues and proposed modifications to the Unit Power Sales Agreement for the executive incentive compensation issues. In June 2022 the FERC trial staff submitted revised answering testimony, in which it recommended additional refunds associated with the accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. Based on the testimony revisions, the FERC trial staff’s recommended refunds total $106.6 million, exclusive of any tax gross-up or FERC awarded interest. Also in June 2022, System Energy filed revised and supplemental cross-answering testimony to respond to the changes in the FERC trial staff’s testimony and oppose its revised recommendation.

In May 2022 the LPSC, the APSC, and the City Council filed rebuttal testimony. The LPSC’s testimony asserts new claims, including that: (1) certain of the sale-leaseback transaction costs may have been imprudently incurred; (2) accumulated deferred income taxes associated with sale-leaseback transaction costs should have been included in rate base; (3) accumulated deferred income taxes associated with federal investment tax credits should have been excluded from rate base; (4) monthly net operating loss accumulated deferred income taxes should have been excluded from rate base; and (5) several categories of proposed rate changes, including executive incentive compensation, air travel, industry dues, and legal costs, also warrant historical refunds. The LPSC’s rebuttal testimony argues that refunds for the alleged tariff violations and other claims must be calculated by rerunning the Unit Power Sales Agreement formula rate; however, it includes estimates of refunds associated with some, but not all, of its claims, totaling $286 million without interest. The City Council’s rebuttal testimony also proposes a new, alternate theory and claim for relief regarding System Energy’s participation in the Entergy System money pool, under which it calculates estimated refunds of approximately $51.7 million. The APSC’s rebuttal testimony agrees with the LPSC’s direct testimony that retained earnings should be adjusted in a comprehensive refund calculation. The testimony quantifies the estimated impacts of three issues: (1) a $1.5 million reduction in the revenue requirement under the Unit Power Sales Agreement if System Energy’s borrowings from the money pool are included in short-term debt; (2) a $1.9 million reduction in the revenue requirement if System Energy’s allocated share of money pool earnings are credited through the Unit Power Sales Agreement; and (3) a $1.9 million reduction in the revenue requirement for every $50 million of refunds ordered in a given year, without interest.

In June 2022 a new procedural schedule was adopted, providing for additional rounds of testimony, for the hearing to begin in September 2022, and for the initial decision to be issued in February 2023. In July 2022, System Energy filed responsive rebuttal testimony responding to the new claims in the LPSC’s and the City Council’s rebuttal testimony. Also in July 2022 the LPSC filed supplemental rebuttal testimony responding to System Energy’s revised cross-answering testimony.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the

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financial impact of the first through fourth allegations is approximately $53 million in refunds, excluding interest which will be calculated after a FERC order is issued; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

System Energy Settlement with the MPSC

In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorializes the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered. The settlement therefore limits System Energy’s overall refund exposure associated with the identified proceedings because they will be resolved completely as between the Entergy parties and the MPSC.

The FERC proceedings that are resolved as between the Entergy parties and the MPSC include the Return on Equity and Capital Structure Complaints, the Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue, the Unit Power Sales Agreement Complaint, and the Grand Gulf Prudence Complaint, all of which are discussed in Note 2 to the financial statements in the Form 10-K, and updated above. They also include the proceedings concerning System Energy’s return of excess accumulated deferred income taxes after the Tax Cuts and Jobs Act and the proceedings established to address System Energy’s October 2020 and December 2020 Federal Power Act section 205 filings to provide credits to customers related to the IRS’s decision as to the uncertain decommissioning tax position, also as all discussed in Note 2 to the financial statements in the Form 10-K. The settlement also resolves the MPSC’s involvement in the formal challenge filed by the retail regulators of System Energy’s customers in connection with the implementation of the Unit Power Sales Agreement annual formula rate protocols for the 2020 test year, which is discussed above.

The settlement provides for a black-box refund of $235 million from System Energy to Entergy Mississippi, which will be paid within 120 days of the settlement’s effective date (either the date of the FERC approval of the settlement without material modification, or the date that all settling parties agree to accept modifications or otherwise modify the settlement in response to a proposed material modification by the FERC). In addition, beginning with the July 2022 service month, the settlement provides for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates.

The settlement is expressly contingent upon the approval of the FERC and the MPSC. It was approved by the MPSC in June 2022. The remaining retail regulators of Entergy’s utility operating company purchasers under the Unit Power Sales Agreement (the APSC, the LPSC, and the City Council) may elect to join the settlement. If all of them elect to do so under the terms of the settlement, then the total black-box refund payment by System Energy would be $588.25 million, and the prospective rate adjustments would apply to all purchasers under the Unit Power Sales Agreement.


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If the FERC approves the settlement in accordance with its terms, then it will become binding upon the Entergy parties and the MPSC even if no additional retail regulators elect to join the settlement. The settlement will have no effect on the rights of non-settling parties to the identified FERC proceedings.

System Energy previously recorded a provision and associated liability of $37 million for elements of the applicable litigation. In June 2022, System Energy recorded a regulatory charge of $551 million ($413 million net-of-tax), increasing the regulatory liability to $588 million, which consists of $235 million for the settlement with the MPSC and $353 million for potential future refunds to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. In August 2022 comments on the settlement were filed by the APSC, the LPSC, the City Council, the FERC trial staff, and a group that refers to itself as the Louisiana Stakeholders, which are three entities that intervened in the Grand Gulf Prudence Complaint proceeding but not any other proceedings that are part of the settlement. The APSC, the LPSC, and the City Council do not intend to join the settlement, but they do not oppose its approval as between the MPSC and the Entergy parties. The FERC trial staff concludes that the settlement is fair, reasonable, and in the public interest. The Louisiana Stakeholders oppose the settlement, alleging it does not resolve the issues raised in the Grand Gulf Prudence Complaint proceeding. Reply comments will be filed later in August 2022.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

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

As discussed in the Form 10-K, 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 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 additional outages.

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 for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were 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 sought an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana requested that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was 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 August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an

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application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage 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, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, Entergy Louisiana reclassified $1.942 billion from utility plant to other regulatory assets.

In May 2022 the securitization financing closed, resulting in the issuance of $3.194 billion principal amount of bonds by Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA), a political subdivision of the State of Louisiana. The securitization was authorized pursuant to the Louisiana Utilities Restoration Corporation Act, Part VIII of Chapter 9 of Title 45 of the Louisiana Revised Statutes, as supplemented by Act 293 of the Louisiana legislature approved in 2021. The LCDA loaned the proceeds to the LURC. Pursuant to Act 293, the LURC contributed the net bond proceeds to a State legislatively authorized and LURC-sponsored trust, Restoration Law Trust I (the storm trust).

Pursuant to Act 293, the net proceeds of the bonds were used by the storm trust to purchase 31,635,718.7221 Class A preferred, non-voting membership interest units (the preferred interests) issued by Entergy Finance Company, LLC, a majority-owned indirect subsidiary of Entergy. Entergy Finance Company is required to make annual distributions (dividends) commencing on December 15, 2022 on the preferred interests issued to the storm trust. These annual dividends received by the storm trust will be distributed to Entergy Louisiana and the LURC, as beneficiaries of the storm trust. Specifically, 1% of the annual dividends received by the storm trust will be distributed to the LURC, for the benefit of customers, and 99% will be distributed to Entergy Louisiana, net of storm trust expenses. The preferred interests have a stated annual cumulative cash dividend rate of 7% and a liquidation price of $100 per unit. The terms of the preferred interests include certain financial covenants to which Entergy Finance Company is subject.

Entergy and Entergy Louisiana do not report the bonds issued by the LCDA on their balance sheets because the bonds are the obligation of the LCDA. The bonds are secured by system restoration property, which is the right granted by law to the LURC to collect a system restoration charge from customers. The system restoration charge is adjusted at least semi-annually to ensure that it is sufficient to service the bonds. Entergy Louisiana collects the system restoration charge on behalf of the LURC and remits the collections to the bond indenture trustee. Entergy Louisiana began collecting the system restoration charge effective with the first billing cycle of June 2022 and the system restoration charge is expected to remain in place up to 15 years. Entergy and Entergy Louisiana do not report the collections as revenue because Entergy Louisiana is merely acting as a billing and collection agent for the LCDA and the LURC. In the remote possibility that the system restoration charge, as well as any funds in the excess subaccount and funds in the debt service reserve account, are insufficient to service the bonds resulting in a payment default, the storm trust is required to liquidate Entergy Finance Company preferred interests in an amount equal to what would be required to cure the default. The estimated value of this indirect guarantee is immaterial.

From the proceeds from the issuance of the preferred membership interests, Entergy Finance Company distributed $1.4 billion to its parent, Entergy Holdings Company, LLC. Subsequently, Entergy Holdings Company liquidated, distributing the $1.4 billion it received from Entergy Finance Company to Entergy Louisiana as holder of

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6,843,780.24 units of Class A, 4,126,940.15 units of Class B, and 2,935,152.69 units of Class C preferred membership interests. Entergy Louisiana had acquired these preferred membership interests with proceeds from previous securitizations of storm restoration costs. Entergy Finance Company loaned the remaining $1.7 billion from the preferred membership interests proceeds to Entergy which used the cash to redeem $650 million of 4.00% Series senior notes due July 2022 and indirectly contributed $1 billion to Entergy Louisiana as a capital contribution.

Entergy Louisiana used the $1 billion capital contribution to fund its Hurricane Ida escrow account and subsequently withdrew the $1 billion from the escrow account. With a portion of the $1 billion withdrawn from the escrow account and the $1.4 billion from the Entergy Holdings Company liquidation, Entergy Louisiana deposited $290 million in a restricted escrow account as a storm damage reserve for future storms, used $1.2 billion to repay its unsecured term loan due June 2023, and used $435 million to redeem a portion of its 0.62% Series mortgage bonds due November 2023.

As discussed in Note 10 to the financial statements herein, the securitization resulted in recognition of a reduction of income tax expense of approximately $290 million by Entergy Louisiana. Entergy’s recognition of reduced income tax expense was offset by other tax charges resulting in a net reduction of income tax expense of $283 million. In recognition of obligations related to an LPSC ancillary order issued as part of the securitization regulatory proceeding, Entergy Louisiana recorded a $224 million ($165 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to share the benefits of the securitization with customers.

As discussed in Note 12 to the financial statements herein, Entergy Louisiana consolidates the storm trust as a variable interest entity and the LURC’s 1% beneficial interest is shown as noncontrolling interest in the financial statements. In second quarter 2022, Entergy Louisiana recorded a charge of $31.6 million in other income to reflect the LURC’s beneficial interest in the trust.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs of $57 million through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow account from which funds were withdrawn to finance costs associated with Hurricane Ida restoration. In June 2022, 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. A procedural schedule has been established with a hearing in December 2022.

Entergy New Orleans

Hurricane Zeta

As discussed in the Form 10-K, 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

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the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, which included $7 million in estimated 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. In May 2022 the City Council advisors issued a report recommending that the City Council find that Entergy New Orleans acted prudently in restoring service following Hurricane Zeta and approximately $33 million in storm restoration costs were prudently incurred and recoverable. Additionally, the advisors concluded that approximately $7 million of the $44 million withdrawn from its funded storm reserve was in excess of Entergy New Orleans’s costs and should be considered in Entergy New Orleans’s application for certification of costs related to Hurricane Ida, as discussed below.

Hurricane Ida

As discussed in the Form 10-K, 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 damage to distribution and transmission infrastructure, including the loss of connectivity to the eastern interconnection. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. In June 2022, Entergy New Orleans filed an application with the City Council requesting approval and certification that storm restoration costs associated with Hurricane Ida of approximately $170 million were reasonable, necessary, and prudently incurred to enable Entergy New Orleans to restore electric service to its customers and to repair Entergy New Orleans’s electric utility infrastructure. Carrying costs through December 2022 related to Hurricane Ida restoration costs were $9 million. Additionally, Entergy New Orleans is requesting approval that the $39 million withdrawal from its funded storm reserve in September 2021 and $7 million in excess storm reserve escrow withdrawals related to Hurricane Zeta and prior miscellaneous storms are properly applied to Hurricane Ida storm restoration costs, the application of which reduces the amount to be recovered from Entergy New Orleans customers by $46 million. The City Council has not yet set a procedural schedule regarding the requested relief, though Entergy New Orleans requested resolution by the end of first quarter 2023. Entergy New Orleans intends to file with the City Council an application proposing a financing method for recovery of costs deemed eligible for recovery.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, 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 July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

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NOTE 3.  EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Mississippi)

Common Stock

Earnings (Loss) per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated statements of operations:
For the Three Months Ended June 30,
20222021
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings (loss) per share
Net income (loss) attributable to Entergy Corporation$159.7 203.4 $0.79 ($6.0)200.8 ($0.03)
Average dilutive effect of:
Stock options0.5 (0.01)— — 
Other equity plans0.5 — — — 
Equity Forwards0.3 — — — 
Diluted earnings (loss) per share$159.7 204.7 $0.78 ($6.0)200.8 ($0.03)

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the three months ended June 30, 2022 and approximately 1 million for the three months ended June 30, 2021.

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated statements of operations:
For the Six Months Ended June 30,
20222021
(In Millions, Except Per Share Data)
IncomeShares$/shareIncomeShares$/share
Basic earnings per share
Net income attributable to Entergy Corporation$436.1 203.2 $2.15 $328.6 200.7 $1.64 
Average dilutive effect of:
Stock options0.5 (0.01)0.4 (0.01)
Other equity plans0.4 (0.01)0.3 — 
Equity forwards0.2 — — — 
Diluted earnings per share$436.1 204.3 $2.13 $328.6 201.4 $1.63 

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the six months ended June 30, 2022 and approximately 1 million for the six months ended June 30, 2021.

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.


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Dividends declared per common share were $1.01 for the three months ended June 30, 2022 and $0.95 for the three months ended June 30, 2021. Dividends declared per common share were $2.02 for the six months ended June 30, 2022 and $1.90 for the six months ended June 30, 2021.

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. Initially, the aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement could not exceed an aggregate gross sales price of $1 billion. In May 2022, Entergy increased by $1 billion the aggregate gross sales price authorized under the at the market equity distribution program. As of June 30, 2022, an aggregate gross sales price of approximately $884 million has been sold under the at the market equity distribution program. See Note 7 to the financial statements in the Form 10-K for discussion of the common stock issued and unsettled forward sale agreements entered into during 2021.

During the six months ended June 30, 2022, there were no shares of common stock issued under the at the market equity distribution program. During the six months ended June 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 2022, Entergy entered into a forward sale agreement for 2,124,086 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 December 29, 2023, either (i) physically settle the transactions by issuing the total of 2,124,086 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 $116.94 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 2,124,086 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $250.9 million. In connection with the sale of these shares, Entergy paid the forward sellers fees of approximately $2.5 million, which have not been deducted from the gross sales price. Entergy did not receive any proceeds from such sales of borrowed shares.

In March 2022, Entergy entered into a forward sale agreement for 1,538,010 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 29, 2023, either (i) physically settle the transactions by issuing the total of 1,538,010 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 $108.14 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 1,538,010 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million. In connection with the sale of these shares, Entergy paid the forward sellers fees of approximately $1.7 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 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 investment bank in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially $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 sale of these shares, Entergy paid the forward sellers fees of approximately $0.5 million, which have not been deducted from the gross sales price. Entergy Corporation 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 six months ended June 30, 2022, approximately 1 million shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.

Treasury Stock

During the six months ended June 30, 2022, Entergy Corporation issued 763,847 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2022.

Retained Earnings

On July 29, 2022, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.01 per share, payable on September 1, 2022 to holders of record as of August 11, 2022.


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Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2022 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, April 1, 2022($1,011)($330,319)($5,248)($336,578)
Other comprehensive income (loss) before reclassifications(14)— 4,101 4,087 
Amounts reclassified from accumulated other comprehensive income38 6,045 2,370 8,453 
Net other comprehensive income for the period24 6,045 6,471 12,540 
Ending balance, June 30, 2022($987)($324,274)$1,223 ($324,038)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the
three months ended June 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, April 1, 2021($861)($511,609)$11,963 ($500,507)
Other comprehensive income (loss) before reclassifications(14)— 648 634 
Amounts reclassified from accumulated other comprehensive income (loss)(208)22,098 (756)21,134 
Net other comprehensive income (loss) for the period(222)22,098 (108)21,768 
Ending balance, June 30, 2021($1,083)($489,511)$11,855 ($478,739)


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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2022 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, 2022($1,035)($338,647)$7,154 ($332,528)
Other comprehensive income (loss) before reclassifications(29)— (11,774)(11,803)
Amounts reclassified from accumulated other comprehensive income (loss)77 14,373 5,843 20,293 
Net other comprehensive income (loss) for the period48 14,373 (5,931)8,490 
Ending balance, June 30, 2022($987)($324,274)$1,223 ($324,038)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 reclassifications1,467 — (44,653)(43,186)
Amounts reclassified from accumulated other comprehensive income (loss)(31,269)45,065 (142)13,654 
Net other comprehensive income (loss) for the period(29,802)45,065 (44,795)(29,532)
Ending balance, June 30, 2021($1,083)($489,511)$11,855 ($478,739)


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The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2022 and 2021:

Pension and Other
Postretirement Liabilities
20222021
(In Thousands)
Beginning balance, April 1,$7,665 $3,920 
Amounts reclassified from accumulated other comprehensive income (loss)(491)588 
Net other comprehensive income (loss) for the period(491)588 
Ending balance, June 30,$7,174 $4,508 

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2022 and 2021:
Pension and Other
Postretirement Liabilities
20222021
(In Thousands)
Beginning balance, January 1,$8,278 $4,327 
Amounts reclassified from accumulated other comprehensive income (loss)(1,104)181 
Net other comprehensive income (loss) for the period(1,104)181 
Ending balance, June 30,$7,174 $4,508 

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2022 and 2021 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20222021
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$— $312 Competitive business operating revenues
   Interest rate swaps(48)(48)Miscellaneous - net
Total realized gain (loss) on cash flow hedges(48)264 
Income taxes10 (56)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)($38)$208 
Pension and other postretirement liabilities
   Amortization of prior-service credit$3,837 $5,248 (a)
   Amortization of loss(10,979)(27,534)(a)
   Settlement loss(545)(6,043)(a)
Total amortization(7,687)(28,329)
Income taxes1,642 6,231 Income taxes
Total amortization (net of tax)($6,045)($22,098)
Net unrealized investment gain (loss)
Realized gain (loss)($3,750)$1,196 Interest and investment income
Income taxes1,380 (440)Income taxes
Total realized investment gain (loss) (net of tax)($2,370)$756 
Total reclassifications for the period (net of tax)($8,453)($21,134)
(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 for the six months ended June 30, 2022 and 2021 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20222021
(In Thousands)
Cash flow hedges net unrealized gain (loss)
   Power contracts$— $39,679 Competitive business operating revenues
   Interest rate swaps(97)(97)Miscellaneous - net
Total realized gain (loss) on cash flow hedges(97)39,582 
Income taxes20 (8,313)Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)($77)$31,269 
Pension and other postretirement liabilities
   Amortization of prior-service credit$7,674 $10,496 (a)
   Amortization of loss(24,904)(62,063)(a)
   Settlement loss(1,327)(6,043)(a)
Total amortization(18,557)(57,610)
Income taxes4,184 12,545 Income taxes
Total amortization (net of tax)($14,373)($45,065)
Net unrealized investment gain (loss)
Realized gain (loss)($9,245)$224 Interest and investment income
Income taxes3,402 (82)Income taxes
Total realized investment gain (loss) (net of tax)($5,843)$142 
Total reclassifications for the period (net of tax)($20,293)($13,654)

(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 June 30, 2022 and 2021 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20222021
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$1,158 $1,230 (a)
   Amortization of loss(308)(626)(a)
   Settlement loss(178)(1,400)(a)
Total amortization672 (796)
Income taxes(181)208 Income taxes
Total amortization (net of tax)491 (588)
Total reclassifications for the period (net of tax)$491 ($588)

(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 six months ended June 30, 2022 and 2021 were as follows:
Amounts reclassified
from AOCI		Income Statement Location
20222021
(In Thousands)
Pension and other postretirement liabilities
   Amortization of prior-service credit$2,316 $2,460 (a)
   Amortization of loss(627)(1,305)(a)
   Settlement loss(178)(1,400)(a)
Total amortization1,511 (245)
Income taxes(407)64 Income taxes
Total amortization (net of tax)1,104 (181)
Total reclassifications for the period (net of tax)$1,104 ($181)

(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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Noncontrolling Interest

The dollar value of noncontrolling interest for Entergy Louisiana as of June 30, 2022 and December 31, 2021 is presented below:
20222021
(In Thousands)
Entergy Louisiana Noncontrolling Interest
Restoration Law Trust I (a)
$31,894 $— 
Total Noncontrolling Interest$31,894 $— 

(a)Restoration Law Trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Restoration Law Trust I holds preferred membership interests issued by Entergy Finance Company and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests will be distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates Restoration Law Trust I and the LURC’s 1% beneficial interest is shown as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements herein for a discussion of the Entergy Louisiana securitization.

The dollar value of noncontrolling interest for Entergy Mississippi as of June 30, 2022 and December 31, 2021 is presented below:
20222021
(In Thousands)
Entergy Mississippi Noncontrolling Interest
MS Sunflower Partnership, LLC (a)
$9,595 $— 
Total Noncontrolling Interest$9,595 $— 

(a)In May 2022, MS Sunflower Partnership, LLC, a tax equity partnership between Entergy Mississippi and a tax equity investor, made the initial payment for the purchase of the Sunflower Solar facility. A final payment will be made upon substantial completion of the facility and is currently expected in third quarter 2022. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is shown as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements in the Form 10-K for further discussion of the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC which is the basis for treatment of Entergy Mississippi’s investment in MS Sunflower Partnership, LLC.


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 2027.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the six months

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ended June 30, 2022 was 1.96% on the drawn portion of the facility.  As of June 30, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,500$150$3$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of June 30, 2022, Entergy Corporation had $1.398 billion of commercial paper outstanding.  The weighted-average interest rate for the six months ended June 30, 2022 was 0.91%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2022 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2022		Letters of Credit
Outstanding as of
June 30, 2022
Entergy ArkansasApril 2023$25 million (b)3.19%$—$—
Entergy ArkansasJune 2027$150 million (c)2.75%$—$—
Entergy LouisianaJune 2027$350 million (c)2.88%$—$—
Entergy MississippiApril 2023$45 million (d)3.13%$—$—
Entergy MississippiApril 2023$40 million (d)3.13%$—$—
Entergy MississippiApril 2023$10 million (d)3.13%$—$—
Entergy MississippiJuly 2024$150 million2.42%$100 million$—
Entergy New OrleansJune 2024$25 million (c)3.29%$—$—
Entergy TexasJune 2027$150 million (c)2.88%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2022 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
(d)Borrowings under the short-term 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 for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.


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In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2022:
CompanyAmount of
Uncommitted Facility		Letter of Credit FeeLetters of Credit
Issued as of
June 30, 2022
(a) (b)
Entergy Arkansas$25 million0.78%$4.5 million
Entergy Louisiana$125 million 0.78%$70.0 million
Entergy Mississippi$65 million0.78%$4.3 million
Entergy New Orleans$15 million1.625%$1.0 million
Entergy Texas$80 million0.875%$79.6 million

(a)As of June 30, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.4 million for Entergy Mississippi and $5.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2022, in addition to the $4.3 million MISO letters of credit, Entergy Mississippi had $7 million in 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 short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 June 30, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$—
Entergy Texas$200$—
System Energy$200$—

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 2023. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of June 30, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the six months ended June 30, 2022 was 2.02% 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.

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Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2022:
CompanyExpiration
Date 		Amount
of
Facility		Weighted
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2022
(Dollars in Millions)
Entergy Arkansas VIEJune 2025$801.55%$12
Entergy Louisiana River Bend VIEJune 2025$1051.37%$20
Entergy Louisiana Waterford VIEJune 2025$1051.49%$70.4
System Energy VIEJune 2025$1201.54%$93.8

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

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. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2022 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.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.


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Debt Issuances and Retirements

(Entergy Corporation)

In June 2022, Entergy Corporation redeemed $650 million of 4.00% Series senior notes due July 2022.

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas used the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the six months ended June 30, 2022 was 1.18%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Entergy Louisiana repaid the full amount of the loan in June 2022.

In May 2022, Entergy Louisiana redeemed, prior to maturity, a portion of its 0.62% Series mortgage bonds due November 2023. Entergy Louisiana redeemed $435 million in aggregate principal amount of the bonds, leaving $665 million in aggregate principal amount outstanding.

(Entergy Mississippi)

In June 2022, Entergy Mississippi entered into a term loan credit agreement providing a $150 million unsecured term loan due December 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The rate set as of June 30, 2022 was 2.47%. Entergy Mississippi used the funds for general corporate purposes.

(System Energy)

In May 2022, System Energy entered into a term loan credit agreement providing a $50 million term loan due November 2023. The term loan is secured by a series of first mortgage bonds and bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the six months ended June 30, 2022 was 2.20%. System Energy used the funds for general corporate purposes.


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Entergy Texas Securitization Bonds

In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:
Amount
(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028
$100,000 
Tranche A-2 (3.697%) due December 2036
190,850 
Total senior secured restoration bonds$290,850 

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2022 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$25,452,926 $23,227,270 
Entergy Arkansas$4,175,929 $3,805,958 
Entergy Louisiana$10,369,840 $9,626,860 
Entergy Mississippi$2,430,499 $2,134,560 
Entergy New Orleans$782,815 $743,715 
Entergy Texas$2,612,874 $2,360,498 
System Energy$798,615 $743,102 

(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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The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$25,880,901 $27,061,171 
Entergy Arkansas$3,958,862 $4,176,577 
Entergy Louisiana$10,914,346 $11,492,650 
Entergy Mississippi$2,179,989 $2,346,230 
Entergy New Orleans$788,165 $765,538 
Entergy Texas$2,354,148 $2,483,995 
System Energy$741,296 $743,040 

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


NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

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

Stock Options

Entergy granted options on 444,028 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2022 with a fair value of $16.25 per option.  As of June 30, 2022, there were options on 2,871,099 shares of common stock outstanding with a weighted-average exercise price of $96.18.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2022.  The aggregate intrinsic value of the stock options outstanding as of June 30, 2022 was $56.7 million.

The following table includes financial information for outstanding stock options for the three months ended June 30, 2022 and 2021:
20222021
(In Millions)
Compensation expense included in Entergy’s consolidated net income$1.2 $1.0 
Tax benefit recognized in Entergy’s consolidated net income$0.3 $0.2 
Compensation cost capitalized as part of fixed assets and materials and supplies$0.4 $0.4 


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The following table includes financial information for outstanding stock options for the six months ended June 30, 2022 and 2021:
20222021
(In Millions)
Compensation expense included in Entergy’s net income$2.3 $2.0 
Tax benefit recognized in Entergy’s net income$0.6 $0.5 
Compensation cost capitalized as part of fixed assets and materials and supplies$0.8 $0.8 

Other Equity Awards

In January 2022 the Board approved and Entergy granted 328,849 restricted stock awards and 170,966 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 27, 2022 and were valued at $109.59 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, a credit measure – adjusted funds from operations/debt ratio – was selected for the 2022-2024 performance period. Performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure.  The performance units were granted on January 27, 2022 and eighty percent were valued at $138.99 per share based on various factors, primarily market conditions; and twenty percent were valued at $109.59 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 June 30, 2022 and 2021:
20222021
(In Millions)
Compensation expense included in Entergy’s consolidated net income$10.6 $9.7 
Tax benefit recognized in Entergy’s consolidated net income$2.7 $2.5 
Compensation cost capitalized as part of fixed assets and materials and supplies$4.3 $4.0 


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The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2022 and 2021:
20222021
(In Millions)
Compensation expense included in Entergy’s net income$22.0 $20.5 
Tax benefit recognized in Entergy’s net income$5.6 $5.2 
Compensation cost capitalized as part of fixed assets and materials and supplies$8.7 $8.0 


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 costs, including amounts capitalized, for the second quarters of 2022 and 2021, included the following components:
20222021
(In Thousands)
Service cost - benefits earned during the period$36,977 $42,951 
Interest cost on projected benefit obligation52,676 47,382 
Expected return on assets(103,085)(106,039)
Amortization of net loss56,413 92,799 
Settlement charges22,653 111,549 
Net pension costs$65,634 $188,642 

Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2022 and 2021, included the following components:
20222021
(In Thousands)
Service cost - benefits earned during the period$74,637 $88,191 
Interest cost on projected benefit obligation103,795 93,480 
Expected return on assets(206,692)(211,753)
Amortization of net loss116,992 197,190 
Settlement charges22,653 111,549 
Net pension costs$111,385 $278,657 

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The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the second quarters of 2022 and 2021, included the following components:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$6,699 $9,007 $2,075 $752 $1,579 $2,001 
Interest cost on projected benefit obligation9,761 10,684 2,796 1,139 2,272 2,394 
Expected return on assets(19,031)(21,060)(5,164)(2,515)(4,905)(4,586)
Amortization of net loss12,848 12,302 3,620 1,368 2,439 3,171 
Settlement charges11,496 4,461 2,208 — 2,466 2,023 
Net pension cost$21,773 $15,394 $5,535 $744 $3,851 $5,003 

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$7,255 $9,759 $2,304 $774 $1,757 $2,253 
Interest cost on projected benefit obligation8,752 9,864 2,571 1,079 2,052 2,236 
Expected return on assets(19,640)(22,516)(5,600)(2,641)(5,272)(4,804)
Amortization of net loss18,250 17,890 5,309 2,069 3,415 4,933 
Settlement charges24,386 34,992 7,762 3,585 6,626 4,638 
Net pension cost$39,003 $49,989 $12,346 $4,866 $8,578 $9,256 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the six months ended June 30, 2022 and 2021, included the following components:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$13,557 $18,144 $4,205 $1,504 $3,211 $4,046 
Interest cost on projected benefit obligation19,078 21,183 5,474 2,278 4,447 4,732 
Expected return on assets(38,278)(42,193)(10,367)(5,030)(9,842)(9,209)
Amortization of net loss26,274 24,899 7,430 2,736 4,994 6,437 
Settlement charges11,496 4,461 2,208 — 2,466 2,023 
Net pension cost$32,127 $26,494 $8,950 $1,488 $5,276 $8,029 


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2021Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$14,674 $19,803 $4,668 $1,569 $3,557 $4,566 
Interest cost on projected benefit obligation17,092 19,425 5,034 2,108 4,002 4,378 
Expected return on assets(39,311)(45,055)(11,186)(5,263)(10,510)(9,583)
Amortization of net loss37,552 37,093 10,976 4,340 7,126 10,258 
Settlement charges24,386 34,992 7,762 3,585 6,626 4,638 
Net pension cost$54,393 $66,258 $17,254 $6,339 $10,801 $14,257 

Non-Qualified Net Pension Cost

Entergy recognized $7.2 million and $4.6 million in pension cost for its non-qualified pension plans in the second quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter of 2022 were settlement charges of $2.5 million related to the payment of lump sum benefits out of the plan. In the second quarter of 2021, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $17.4 million and $9.2 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2022 were settlement charges of $7.8 million related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2021, there were no settlement charges 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 second quarters of 2022 and 2021:

Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2022$71 $26 $79 $27 $88 
2021$90 $44 $96 $8 $115 

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2022 and 2021:

Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2022$143 $53 $161 $56 $303 
2021$180 $88 $192 $16 $230 

Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 30, 2022 were settlement charges of $2 thousand related to the payment of lump sum benefits out of the plan. Entergy Texas’ non-qualified pension costs for the six months ended June 30, 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.


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Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2022 and 2021, included the following components:
20222021
(In Thousands)
Service cost - benefits earned during the period$6,184 $6,645 
Interest cost on accumulated postretirement benefit obligation (APBO)6,827 5,320 
Expected return on assets(10,855)(10,805)
Amortization of prior service credit(6,388)(8,267)
Amortization of net loss1,083 713 
Net other postretirement benefit income($3,149)($6,394)

Entergy’s other postretirement benefit income, including amounts capitalized, for the six months ended June 30, 2022 and 2021, included the following components:
 20222021
 (In Thousands)
Service cost - benefits earned during the period$12,368 $13,290 
Interest cost on accumulated postretirement benefit obligation (APBO)13,654 10,640 
Expected return on assets(21,710)(21,610)
Amortization of prior service credit(12,776)(16,534)
Amortization of net loss2,166 1,426 
Net other postretirement benefit income($6,298)($12,788)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2022 and 2021, included the following components:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,114 $1,408 $339 $99 $331 $310 
Interest cost on APBO1,263 1,443 350 174 399 279 
Expected return on assets(4,483)— (1,394)(1,499)(2,568)(791)
Amortization of prior service cost/(credit)471 (1,158)(443)(229)(1,093)(80)
Amortization of net (gain) loss218 (186)56 (225)162 30 
Net other postretirement benefit cost (income) ($1,417)$1,507 ($1,092)($1,680)($2,769)($252)


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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)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2022 and 2021, included the following components:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$2,228 $2,816 $678 $198 $662 $620 
Interest cost on APBO2,526 2,886 700 348 798 558 
Expected return on assets(8,966)— (2,788)(2,998)(5,136)(1,582)
Amortization of prior service cost/(credit)942 (2,316)(886)(458)(2,186)(160)
Amortization of net (gain) loss436 (372)112 (450)324 60 
Net other postretirement benefit cost (income)($2,834)$3,014 ($2,184)($3,360)($5,538)($504)

2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$2,068 $3,088 $724 $218 $692 $670 
Interest cost on APBO1,864 2,260 556 260 634 440 
Expected return on assets(9,010)— (2,768)(2,876)(5,096)(1,578)
Amortization of prior service credit(560)(2,460)(888)(458)(1,872)(218)
Amortization of net (gain) loss98 (182)38 (356)200 30 
Net other postretirement benefit cost (income)($5,540)$2,706 ($2,338)($3,212)($5,442)($656)


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Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2022 and 2021:

2022Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $4,014 ($177)$3,837 
Amortization of net loss(10,035)(596)(348)(10,979)
Settlement loss(178)— (367)(545)
($10,213)$3,418 ($892)($7,687)
Entergy Louisiana
Amortization of prior service credit$— $1,158 $— $1,158 
Amortization of net gain (loss)(493)186 (1)(308)
Settlement loss(178)— — ($178)
($671)$1,344 ($1)$672 

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(26,443)(496)(595)(27,534)
Settlement loss(6,043)— — (6,043)
($32,486)$4,792 ($635)($28,329)
Entergy Louisiana
Amortization of prior service credit$— $1,230 $— $1,230 
Amortization of net gain (loss)(716)91 (1)(626)
Settlement loss(1,400)— — (1,400)
($2,116)$1,321 ($1)($796)


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Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2022 and 2021:
2022Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $8,028 ($354)$7,674 
Amortization of net loss(22,945)(1,192)(767)(24,904)
Settlement loss(178)— (1,149)(1,327)
($23,123)$6,836 ($2,270)($18,557)
Entergy Louisiana
Amortization of prior service credit$— $2,316 $— $2,316 
Amortization of net gain (loss)(997)372 (2)(627)
Settlement loss(178)— — (178)
($1,175)$2,688 ($2)$1,511 

2021Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service (cost) credit$— $10,576 ($80)$10,496 
Amortization of net loss(59,883)(990)(1,190)(62,063)
Settlement loss(6,043)— — (6,043)
($65,926)$9,586 ($1,270)($57,610)
Entergy Louisiana
Amortization of prior service credit$— $2,460 $— $2,460 
Amortization of net gain (loss)(1,484)182 (3)(1,305)
Settlement loss(1,400)— — (1,400)
($2,884)$2,642 ($3)($245)

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.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees exceeded the sum of the Plan’s 2022 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 plan’s pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy each participate in the Entergy Corporation Retirement Plan for 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

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manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the base rate case that was filed with the PUCT in July 2022 and a reasonable amortization period will be determined by the PUCT. At June 30, 2022, the balance in this reserve was approximately $15.7 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of June 30, 2022, Entergy had contributed $101 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 2022:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2022 pension contributions$40,840 $22,917 $12,852 $922 $1,924 $12,760 
Pension contributions made through June 2022$21,532 $13,410 $5,442 $922 $1,486 $6,187 
Remaining estimated pension contributions to be made in 2022$19,308 $9,507 $7,410 $— $438 $6,573 


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 June 30, 2022 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 and Note 14 to the financial statements herein for discussion of the shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants. With the sale of Palisades in June 2022, Entergy completed its multi-year strategy to exit the merchant nuclear power business. “All Other” includes the parent company, Entergy Corporation, and other business activity.


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Entergy’s segment financial information for the second quarters of 2022 and 2021 were as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsConsolidated
(In Thousands)
2022
Operating revenues$3,306,269 $88,933 $— ($6)$3,395,196 
Income taxes($371,704)$25,233 ($13,172)$— ($359,643)
Consolidated net income (loss)$156,548 $87,386 ($36,672)($43,251)$164,011 
2021
Operating revenues$2,673,385 $148,656 $31 ($2)$2,822,070 
Income taxes$71,360 ($71,696)($18,080)$— ($18,416)
Consolidated net income (loss)$329,936 ($274,648)($24,784)($31,898)($1,394)

Entergy’s segment financial information for the six months ended June 30, 2022 and 2021 were as follows:
UtilityEntergy
Wholesale
Commodities		All OtherEliminationsConsolidated
(In Thousands)
2022
Operating revenues$6,034,425 $238,711 $— ($14)$6,273,122 
Income taxes($296,346)$28,089 ($24,888)$— ($293,145)
Consolidated net income (loss)$499,704 $95,245 ($76,148)($75,197)$443,604 
Total assets as of June 30, 2022$60,525,686 $528,296 $548,740 ($3,775,143)$57,827,579 
2021
Operating revenues$5,270,000 $396,874 $54 ($21)$5,666,907 
Income taxes$131,094 ($56,135)($27,433)$— $47,526 
Consolidated net income (loss)$690,535 ($236,525)($52,464)($63,796)$337,750 
Total assets as of December 31, 2021$59,733,625 $1,242,675 $561,168 ($2,083,226)$59,454,242 

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management implemented a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which included the shutdown and sale of all plants in its merchant nuclear fleet. With the sale of Palisades in June 2022, Entergy has exited the merchant nuclear power business. The decisions to shut down these plants and the related 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 second quarters of 2022 and 2021 were comprised of the following:
20222021
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 April 1,$41 $— $41 $157 $14 $171 
Restructuring costs accrued(1)— (1)(6)1 (5)
Cash paid out— — — 118 15 133 
Balance as of June 30,$40 $— $40 $33 $— $33 

In addition, Entergy Wholesale Commodities recorded a gain of $166 million in the second quarter 2022 as a result of the sale of the Palisades plant, as well as $1 million of impairment and other related charges, and $342 million in the second quarter 2021 of impairment and other related charges, including a $340 million loss as a result of the sale of the Indian Point Energy Center, associated with these strategic decisions and transactions.

Total restructuring charges for the six months ended June 30, 2022 and 2021 were comprised of the following:
20222021
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,$37 $— $37 $145 $14 $159 
Restructuring costs accrued3 — 3 7 1 8 
Cash paid out— — — 119 15 134 
Balance as of June 30,$40 $— $40 $33 $— $33 

In addition, Entergy Wholesale Commodities recorded a gain of $166 million in the six months ended June 30, 2022 as a result of the sale of the Palisades plant, as well as $1 million of impairment and other related charges, and $345 million in the six months ended June 30, 2021 of impairment and other related charges, including a $340 million loss as a result of the sale of the Indian Point Energy Center, associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with its exit from the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $3 million has been incurred as of June 30, 2022.


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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 was 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.  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. 

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 contained provisions that required 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 was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of June 30, 2022 and December 31, 2021. As of June 30, 2022, $12 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

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 has executed natural gas swaps and options as of June 30, 2022 is 1.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2022 is 6 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2022 is 27,681,400 MMBtu for Entergy, including 12,800,000 MMBtu for Entergy Louisiana, 14,771,300 MMBtu for Entergy Mississippi, and 110,100 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.

During the second quarter 2022, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2022 through May 31, 2023. 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

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transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2022 is 135,179 GWh for Entergy, including 30,477 GWh for Entergy Arkansas, 61,242 GWh for Entergy Louisiana, 14,621 GWh for Entergy Mississippi, 5,720 GWh for Entergy New Orleans, and 22,950 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of June 30, 2022 and as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2022 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$37$—$37Utility
Natural gas swaps and optionsOther deferred debits and other assets$9$—$9Utility
Financial transmission rightsPrepayments and other$13($1)$12Utility 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, 2021 are shown in the table below.  
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$6$—$6Utility
Natural gas swaps and optionsOther deferred debits and other assets$5$—$5Utility
Financial transmission rightsPrepayments and other$4$—$4Utility and Entergy Wholesale Commodities
Liabilities:    
Natural gas swaps and optionsOther current liabilities$7$—$7Utility

(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 $12 million posted as of June 30, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2022.

As discussed above, 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. For the three months ended June 30, 2021, there were no effects resulting from Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations.

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2021 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)
Electricity swaps and options$2Competitive businesses operating revenues$40

(a)    Before taxes of $8 million for the six months ended June 30, 2021


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Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated 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 would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the three months ended June 30, 2022 and 2021 were as follows:

InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2022
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$23
Financial transmission rightsPurchased power expense(b)$37
2021
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$18
Financial transmission rightsPurchased power expense(b)$16
Electricity swaps and options (c)Competitive business operating revenues$—

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2022 and 2021 were as follows:
InstrumentIncome Statement
location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2022
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale(a)$78
Financial transmission rightsPurchased power(b)$60
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale(a)$25
Financial transmission rightsPurchased power(b)$144
Electricity swaps and options (c)Competitive business operating revenues($2)


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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 prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2022 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$16.1$—$16.1Entergy Louisiana
Natural gas swaps and optionsOther deferred debits and other assets$8.7$—$8.7Entergy Louisiana
Natural gas swapsPrepayments and other$20.6$—$20.6Entergy Mississippi
Financial transmission rightsPrepayments and other$4.5($0.1)$4.4Entergy Arkansas
Financial transmission rightsPrepayments and other$5.3($0.6)$4.7Entergy Louisiana
Financial transmission rightsPrepayments and other$0.5$—$0.5Entergy Mississippi
Financial transmission rightsPrepayments and other$0.6$—$0.6Entergy New Orleans
Financial transmission rightsPrepayments and other$1.7($0.2)$1.5Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$0.2$—$0.2
Entergy New Orleans


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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, 2021 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 $5.7$—$5.7Entergy Louisiana
Natural gas swaps and optionsOther deferred debits and other assets$5.3$—$5.3Entergy Louisiana
Financial transmission rightsPrepayments and other$2.3$—$2.3Entergy Arkansas
Financial transmission rightsPrepayments and other$0.6$—$0.6Entergy Louisiana
Financial transmission rightsPrepayments and other$0.3$—$0.3Entergy Mississippi
Financial transmission rightsPrepayments and other$0.1$—$0.1Entergy New Orleans
Financial transmission rightsPrepayments and other$0.8$—$0.8Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$6.7$—$6.7Entergy Mississippi
Natural gas swapsOther current liabilities$0.5$—$0.5Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)As of June 30, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Mississippi and $5.3 million for Entergy Texas. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 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 June 30, 2022 and 2021 were as follows:

InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2022
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$8.7(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$14.6(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($0.2)(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$16.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$16.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.2(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$1.6(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$1.0(b)Entergy Texas
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$4.9(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$13.2(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.1(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$3.4(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$5.9(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$4.8(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 six months ended June 30, 2022 and 2021 were as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2022
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$19.8(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$57.4(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.9(a)Entergy New Orleans
Financial transmission rightsPurchased power$23.5(b)Entergy Arkansas
Financial transmission rightsPurchased power$25.5(b)Entergy Louisiana
Financial transmission rightsPurchased power$3.2(b)Entergy Mississippi
Financial transmission rightsPurchased power$2.4(b)Entergy New Orleans
Financial transmission rightsPurchased power$4.9(b)Entergy Texas
2021
Natural gas swaps and optionsFuel, fuel-related expenses, and gas purchased for resale$6.7(a)Entergy Louisiana
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$18.3(a)Entergy Mississippi
Financial transmission rightsPurchased power$29.5(b)Entergy Arkansas
Financial transmission rightsPurchased power$18.2(b)Entergy Louisiana
Financial transmission rightsPurchased power$7.9(b)Entergy Mississippi
Financial transmission rightsPurchased power$2.0(b)Entergy New Orleans
Financial transmission rightsPurchased power$82.7(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 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 are reflected in future rates and

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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.

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.


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The values for power contract assets or liabilities prior to expiration in April 2021 were 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 were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were 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 included: 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 was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed 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 were based on the estimated amount that the contracts were 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 equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were 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 were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was 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 were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, 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 were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were 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 were 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 confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was 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

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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 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 are accounted for at fair value on a recurring basis as of June 30, 2022 and December 31, 2021.  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.
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$514 $— $— $514 
Decommissioning trust funds (a):
Equity securities18 — — 18 
Debt securities (b)598 1,095 — 1,693 
Common trusts (c)2,379 
Securitization recovery trust account28 — — 28 
Escrow accounts331 — — 331 
Gas hedge contracts37 9 — 46 
Financial transmission rights— — 12 12 
$1,526 $1,104 $12 $5,021 

2021Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$398 $— $— $398 
Decommissioning trust funds (a):    
Equity securities132 — — 132 
Debt securities (b)770 1,407 — 2,177 
Common trusts (c)3,205 
Securitization recovery trust account29 — — 29 
Escrow accounts49 — — 49 
Gas hedge contracts6 5 — 11 
Financial transmission rights— — 4 4 
 $1,384 $1,412 $4 $6,005 
Liabilities:    
Gas hedge contracts$7 $— $— $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 value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.4 million as of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

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(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2022 and 2021:

20222021
Financial transmission rightsFinancial transmission rights
(In Millions)
Balance as of April 1,$1 $4 
Total gains (losses) for the period
Included as a regulatory liability/asset32 15 
Issuances of financial transmission rights16 12 
Settlements(37)(16)
Balance as of June 30,$12 $15 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2022 and 2021:
20222021
Financial transmission rightsPower ContractsFinancial transmission rights
(In Millions)
Balance as of January 1,$4 $38 $9 
Total gains (losses) for the period
Included in earnings— (2)3 
Included in other comprehensive income— 2 — 
Included as a regulatory liability/asset52 — 135 
Issuances of financial transmission rights16 — 12 
Settlements(60)(38)(144)
Balance as of June 30,$12 $— $15 

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 are accounted for at fair value on a recurring basis as of June 30, 2022 and December 31, 2021.  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
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$58.2 $— $— $58.2 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities131.6 353.2 — 484.8 
Common trusts (b)705.9 
Financial transmission rights— — 4.4 4.4 
$193.9 $353.2 $4.4 $1,257.4 

2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$4.8 $— $— $4.8 
Decommissioning trust funds (a):
Equity securities16.7 — — 16.7 
Debt securities119.5 406.8 — 526.3 
Common trusts (b)895.4 
Financial transmission rights— — 2.3 2.3 
$141.0 $406.8 $2.3 $1,445.5 

Entergy Louisiana
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$65.7 $— $— $65.7 
Decommissioning trust funds (a):
Equity securities12.6 — — 12.6 
Debt securities225.0 508.3 — 733.3 
Common trusts (b)1,010.6 
Escrow accounts290.1 — — 290.1 
Gas hedge contracts16.1 8.7 — 24.8 
Financial transmission rights— — 4.7 4.7 
$609.5 $517.0 $4.7 $2,141.8 


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2021Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$18.4 $— $— $18.4 
Decommissioning trust funds (a):    
Equity securities20.2 — — 20.2 
Debt securities262.6 531.6 — 794.2 
Common trusts (b)1,300.1 
Gas hedge contracts5.7 5.3 — 11.0 
Financial transmission rights— — 0.6 0.6 
 $306.9 $536.9 $0.6 $2,144.5 

Entergy Mississippi
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$26.1 $— $— $26.1 
Escrow accounts41.1 — — 41.1 
Gas hedge contracts20.6 — — 20.6 
Financial transmission rights— — 0.5 0.5 
$87.8 $— $0.5 $88.3 

2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$47.6 $— $— $47.6 
Escrow accounts48.9 — — 48.9 
Financial transmission rights— — 0.3 0.3 
 $96.5 $— $0.3 $96.8 
Liabilities:
Gas hedge contracts$6.7 $— $— $6.7 

Entergy New Orleans
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$25.7 $— $— $25.7 
Securitization recovery trust account1.7 — — 1.7 
Financial transmission rights— — 0.6 0.6 
$27.4 $— $0.6 $28.0 
Liabilities:
Gas hedge contracts$0.2 $— $— $0.2 


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2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$42.8 $— $— $42.8 
Securitization recovery trust account2.0 — — 2.0 
Financial transmission rights— — 0.1 0.1 
$44.8 $— $0.1 $44.9 
Liabilities:
Gas hedge contracts$0.5 $— $— $0.5 

Entergy Texas
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$14.4 $— $— $14.4 
Securitization recovery trust account26.6 — — 26.6 
Financial transmission rights— — 1.5 1.5 
$41.0 $— $1.5 $42.5 

2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Securitization recovery trust account$26.6 $— $— $26.6 
Financial transmission rights— — 0.8 0.8 
$26.6 $— $0.8 $27.4 

System Energy
2022Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$134.6 $— $— $134.6 
Decommissioning trust funds (a):
Equity securities1.7 — — 1.7 
Debt Securities241.1 233.1 — 474.2 
Common trusts (b)662.9 
$377.4 $233.1 $— $1,273.4 


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2021Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$89.1 $— $— $89.1 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities273.0 251.5 — 524.5 
Common trusts (b)847.9 
$375.0 $251.5 $— $1,474.4 

(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 for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2022.

Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$0.4 $0.3 $0.2 $0.1 $0.5 
Issuances of financial transmission rights5.4 5.3 0.8 0.8 3.9 
Gains (losses) included as a regulatory liability/asset14.6 15.2 1.7 1.3 (1.9)
Settlements(16.0)(16.1)(2.2)(1.6)(1.0)
Balance as of June 30,$4.4 $4.7 $0.5 $0.6 $1.5 

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$1.4 $1.2 $0.3 $0.1 $0.5 
Issuances of financial transmission rights2.8 4.1 1.7 0.4 2.7 
Gains (losses) included as a regulatory liability/asset3.0 5.4 0.8 0.9 5.4 
Settlements(3.4)(5.9)(0.7)(0.8)(4.8)
Balance as of June 30,$3.8 $4.8 $2.1 $0.6 $3.8 

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The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2022.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$2.3 $0.6 $0.3 $0.1 $0.8 
Issuances of financial transmission rights5.4 5.3 0.8 0.8 3.9 
Gains (losses) included as a regulatory liability/asset20.2 24.3 2.6 2.1 1.7 
Settlements(23.5)(25.5)(3.2)(2.4)(4.9)
Balance as of June 30,$4.4 $4.7 $0.5 $0.6 $1.5 

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 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/asset27.8 14.7 7.7 2.1 82.2 
Settlements(29.5)(18.2)(7.9)(2.0)(82.7)
Balance as of June 30,$3.8 $4.8 $2.1 $0.6 $3.8 


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, and Grand Gulf. 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 June 2022, Entergy completed the sale of Palisades to Holtec. As part of the transaction, Entergy transferred the Palisades decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $552 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 did not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds were recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in

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the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2022 on equity securities still held as of June 30, 2022 were ($481) million and ($647) 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 June 30, 2022 and December 31, 2021 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2022
Debt Securities$1,692 $4 $157 
2021
Debt Securities$2,177 $65 $12 

The unrealized gains/(losses) above are reported before deferred taxes of ($1) million as of June 30, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $1,846 million as of June 30, 2022 and $2,125 million as of December 31, 2021.  As of June 30, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.86%, an average duration of approximately 6.57 years, and an average maturity of approximately 10.18 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 June 30, 2022 and December 31, 2021:
June 30, 2022December 31, 2021
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$1,357 $134 $770 $8 
More than 12 months123 23 99 4 
Total$1,480 $157 $869 $12 


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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2022 and December 31, 2021 were as follows:
20222021
(In Millions)
Less than 1 year$65 $— 
1 year - 5 years556 473 
5 years - 10 years501 655 
10 years - 15 years120 389 
15 years - 20 years143 130 
20 years+307 530 
Total$1,692 $2,177 

During the three months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $333 million and $273 million, respectively.  During the three months ended June 30, 2022 and 2021, gross gains of $1 million and $6 million, respectively, and gross losses of $16 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $636 million and $797 million, respectively.  During the six months ended June 30, 2022 and 2021, gross gains of $2 million and $17 million, respectively, and gross losses of $28 million and $12 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 Palisades decommissioning trust fund as of December 31, 2021 was $576 million. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of June 30, 2022 and December 31, 2021 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2022
Debt Securities$484.8 $0.2 $52.2 
2021
Debt Securities$526.3 $11.4 $4.7 

The amortized cost of available-for-sale debt securities was $536.8 million as of June 30, 2022 and $519.6 million as of December 31, 2021.  As of June 30, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.27%, an average duration of approximately 6.22 years, and an average maturity of approximately 7.53 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2022 on equity securities still held as of June 30, 2022 were ($143.5) million and ($193.9) million, respectively. The equity

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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 June 30, 2022 and December 31, 2021:
June 30, 2022December 31, 2021
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$384.2 $40.8 $183.8 $2.9 
More than 12 months64.2 11.4 39.5 1.8 
Total$448.4 $52.2 $223.3 $4.7 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2022 and December 31, 2021 were as follows:
 20222021
 (In Millions)
Less than 1 year$30.1 $— 
1 year - 5 years157.9 91.7 
5 years - 10 years201.4 217.4 
10 years - 15 years43.0 146.0 
15 years - 20 years34.3 35.7 
20 years+18.1 35.5 
Total$484.8 $526.3 

During the three months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $8.8 million and $12.3 million, respectively.  During the three months ended June 30, 2022 and 2021, gross gains of $0.03 million and $0.7 million, respectively, and gross losses of $0.3 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $15.9 million and $26.1 million, respectively.  During the six months ended June 30, 2022 and 2021, gross gains of $0.06 million and $1.6 million, respectively, and gross losses of $0.5 million and $0.1 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 June 30, 2022 and December 31, 2021 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2022
Debt Securities$733.3 $3.2 $56.0 
2021
Debt Securities$794.2 $31.3 $3.3 

The amortized cost of available-for-sale debt securities was $786.1 million as of June 30, 2022 and $766.3 million as of December 31, 2021.  As of June 30, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.50%, an average duration of approximately 6.78 years, and an average maturity of approximately 12.34 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2022 on equity securities still held as of June 30, 2022 were ($202.9) million and ($271.6) 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 June 30, 2022 and December 31, 2021:
June 30, 2022December 31, 2021
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$528.8 $48.5 $206.9 $1.4 
More than 12 months41.8 7.5 42.9 1.9 
Total$570.6 $56.0 $249.8 $3.3 


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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2022 and December 31, 2021 were as follows:
20222021
(In Millions)
Less than 1 year$25.2 $— 
1 year - 5 years198.9 157.8 
5 years - 10 years156.6 173.0 
10 years - 15 years70.3 123.0 
15 years - 20 years78.5 80.2 
20 years+203.8 260.2 
Total$733.3 $794.2 

During the three months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.3 million and $62.5 million, respectively.  During the three months ended June 30, 2022 and 2021, gross gains of $0.2 million and $1.5 million, respectively, and gross losses of $6.7 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $240.9 million and $170.9 million, respectively.  During the six months ended June 30, 2022 and 2021, gross gains of $1.1 million and $4.8 million, respectively, and gross losses of $12.2 million and $3.3 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 June 30, 2022 and December 31, 2021 are summarized as follows:
Fair
Value		Total
Unrealized
Gains		Total
Unrealized
Losses
(In Millions)
2022
Debt Securities$474.3 $0.2 $49.2 
2021
Debt Securities$524.5 $11.8 $2.9 

The amortized cost of available-for-sale debt securities was $523.2 million as of June 30, 2022 and $515.6 million as of December 31, 2021.  As of June 30, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.46%, an average duration of approximately 6.61 years, and an average maturity of approximately 9.51 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2022 on equity securities still held as of June 30, 2022 were ($134.6) million and ($181.8) million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

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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 June 30, 2022 and December 31, 2021:
June 30, 2022December 31, 2021
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$443.6 $45.1 $276.6 $2.3 
More than 12 months16.7 4.1 11.3 0.6 
Total$460.3 $49.2 $287.9 $2.9 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2022 and December 31, 2021 were as follows:
20222021
(In Millions)
Less than 1 year$9.9 $— 
1 year - 5 years199.2 156.8 
5 years - 10 years142.5 161.8 
10 years - 15 years7.2 58.6 
15 years - 20 years29.8 1.9 
20 years+85.7 145.4 
Total$474.3 $524.5 

During the three months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $67.8 million and $101.6 million, respectively.  During the three months ended June 30, 2022 and 2021, gross gains of $0.1 million and $1.9 million, respectively, and gross losses of $4.6 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $104 million and $175.7 million, respectively.  During the six months ended June 30, 2022 and 2021, gross gains of $0.2 million and $3.1 million, respectively, and gross losses of $5.3 million and $1.8 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 June 30, 2022, Entergy did not record an allowance for expected credit losses related to available-for-sale securities. As of December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities was $0.4 million. Entergy did not record any impairments of available-for-sale debt securities for the three months ended June 30, 2022. Entergy recorded $1.5 million in impairments of

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available-for-sale debt securities for the six months ended June 30, 2022. Entergy did not record any impairments of available-for-sale debt securities for the three and six months ended June 30, 2021.


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 June 30,		Six Months
Ended June 30,
2022202120222021
(In Millions)
Entergy$16 $14 $33 $54 
Entergy Arkansas$— $— $— $8 
Entergy Louisiana$9 $8 $18 $15 
Entergy New Orleans$— $— $1 $— 
Entergy Texas$7 $6 $14 $13 
System Energy$— $— $— $18 

Other Tax Matters

As described in Note 2 to the financial statements herein, Entergy Louisiana implemented a securitization authorized under Act 293 of the Louisiana legislature. Act 293 provides that the LURC contribute the net bond proceeds to a LURC-sponsored trust. Over the 15-year term of the Act 293 bonds, the storm trust will make distributions to Entergy Louisiana, a beneficiary of the storm trust, that will not be taxable to Entergy Louisiana. Additionally, Entergy Louisiana will not include the receipt of the system restoration charges in taxable income because the right to receive the system restoration charges has been granted directly to the LURC, and Entergy Louisiana only acts as an agent to collect those charges on behalf of the LURC.

Accordingly, the securitization provides for a tax accounting permanent difference resulting in a net reduction of income tax expense of approximately $290 million, after taking into account a provision for uncertain tax positions, by Entergy Louisiana. Entergy’s recognition of reduced income tax expense was offset by other tax charges resulting in a net reduction of income tax expense of $283 million, after taking into account a provision for uncertain tax positions.

In recognition of its obligations related to an LPSC ancillary order issued as part of the securitization regulatory proceeding, Entergy Louisiana recorded a $224 million ($165 million net-of-tax) regulatory charge and a

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corresponding regulatory liability to reflect its obligation to share the benefits of the securitization with customers. See Note 2 to the financial statements herein for further details of the Entergy Louisiana securitization.


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

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at June 30, 2022 were $401 million for Entergy, $54.8 million for Entergy Arkansas, $198.7 million for Entergy Louisiana, $20.9 million for Entergy Mississippi, $12.7 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $29.2 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.


NOTE 12.  VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, is a variable interest entity and Entergy Texas is the primary beneficiary. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charges. See Note 4 to the financial statements herein for additional details regarding the securitization bonds.

Restoration Law Trust I (the storm trust), a trust consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. The storm trust was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust. As of June 30, 2022, the primary asset held by the storm trust is the $3.2 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheet of Entergy Louisiana. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust is presented as noncontrolling interest in the consolidated balance sheets of Entergy and Entergy Louisiana. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests.


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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 each of the six months ended June 30, 2022 and the six months ended June 30, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of June 30, 2022, AR Searcy Partnership, LLC recorded assets equal to $143 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.5 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest.

MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements herein for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the membership interests do not give Entergy Mississippi or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Mississippi is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion of the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC which is the basis for treatment of Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of June 30, 2022, MS Sunflower Partnership, LLC recorded assets equal to $105.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $95.6 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest.



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

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Utility:
Residential$1,035,063 $855,586 
Commercial715,665 628,703 
Industrial878,194 756,959 
Governmental67,101 61,612 
    Total billed retail2,696,023 2,302,860 
Sales for resale (a)249,035 119,130 
Other electric revenues (b)302,351 187,078 
    Revenues from contracts with customers3,247,409 2,609,068 
Other revenues (c)10,846 32,307 
    Total electric revenues3,258,255 2,641,375 
Natural gas48,008 31,998 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)87,710 146,680 
Other revenues (c)1,223 2,017 
    Total competitive businesses revenues88,933 148,697 
    Total operating revenues$3,395,196 $2,822,070 



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Entergy’s total revenues for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Utility:
Residential$2,021,085 $1,822,441 
Commercial1,350,290 1,201,380 
Industrial1,621,828 1,354,610 
Governmental124,395 118,409 
    Total billed retail5,117,598 4,496,840 
Sales for resale (a)377,994 324,205 
Other electric revenues (b)396,231 267,339 
    Revenues from contracts with customers5,891,823 5,088,384 
Other revenues (c)22,208 91,410 
    Total electric revenues5,914,031 5,179,794 
Natural gas120,369 90,166 
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)232,534 378,794 
Other revenues (c)6,188 18,153 
    Total competitive businesses revenues238,722 396,947 
    Total operating revenues$6,273,122 $5,666,907 


The Utility operating companies’ total revenues for the three months ended June 30, 2022 and 2021 were as follows:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$199,209 $400,915 $143,705 $80,484 $210,750 
Commercial127,230 290,063 118,278 58,801 121,293 
Industrial135,809 536,229 43,738 9,216 153,202 
Governmental5,137 21,841 12,611 20,179 7,333 
    Total billed retail467,385 1,249,048 318,332 168,680 492,578 
Sales for resale (a)156,754 123,231 43,524 36,825 18,133 
Other electric revenues (b)70,820 119,847 41,325 17,443 54,259 
Revenues from contracts with customers694,959 1,492,126 403,181 222,948 564,970 
Other revenues (c)1,980 5,816 2,278 1,136 (379)
    Total electric revenues696,939 1,497,942 405,459 224,084 564,591 
Natural gas— 17,843 — 30,165 — 
    Total operating revenues$696,939 $1,515,785 $405,459 $254,249 $564,591 


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2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$171,103 $340,643 $117,461 $60,186 $166,193 
Commercial111,187 262,351 101,644 51,092 102,429 
Industrial114,284 475,185 36,545 8,028 122,917 
Governmental4,536 21,547 10,873 18,312 6,344 
    Total billed retail401,110 1,099,726 266,523 137,618 397,883 
Sales for resale (a)69,750 74,343 44,050 12,810 19,542 
Other electric revenues (b)73,209 55,745 36,390 9,510 13,577 
Revenues from contracts with customers544,069 1,229,814 346,963 159,938 431,002 
Other revenues (c)6,205 24,765 2,077 (177)(568)
    Total electric revenues550,274 1,254,579 349,040 159,761 430,434 
Natural gas— 13,019 — 18,979 — 
    Total operating revenues$550,274 $1,267,598 $349,040 $178,740 $430,434 


The Utility operating companies’ total revenues for the six months ended June 30, 2022 and 2021 were as follows:

2022Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$426,995 $754,483 $296,643 $139,141 $403,823 
Commercial240,469 547,653 228,939 104,373 228,856 
Industrial245,483 988,182 82,895 15,490 289,778 
Governmental9,598 40,857 24,612 35,211 14,117 
    Total billed retail922,545 2,331,175 633,089 294,215 936,574 
Sales for resale (a)227,167 230,932 65,165 63,365 35,778 
Other electric revenues (b)101,392 161,329 51,662 18,836 65,709 
Revenues from contracts with customers1,251,104 2,723,436 749,916 376,416 1,038,061 
Other revenues (c)4,791 11,743 4,572 2,314 (988)
    Total electric revenues1,255,895 2,735,179 754,488 378,730 1,037,073 
Natural gas— 46,578 — 73,791 — 
    Total operating revenues$1,255,895 $2,781,757 $754,488 $452,521 $1,037,073 

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Notes to Financial Statements
2021Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$408,284 $676,403 $265,097 $126,613 $346,044 
Commercial217,603 487,000 199,580 98,891 198,306 
Industrial217,696 822,194 70,524 14,817 229,379 
Governmental8,791 40,163 21,416 34,692 13,347 
    Total billed retail852,374 2,025,760 556,617 275,013 787,076 
Sales for resale (a)179,834 154,771 84,360 17,506 93,615 
Other electric revenues (b)92,791 99,654 40,341 6,151 31,106 
Revenues from contracts with customers1,124,999 2,280,185 681,318 298,670 911,797 
Other revenues (c)8,661 54,057 4,341 239 (1,143)
    Total electric revenues1,133,660 2,334,242 685,659 298,909 910,654 
Natural gas— 41,000 — 49,166 — 
    Total operating revenues$1,133,660 $2,375,242 $685,659 $348,075 $910,654 
(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 an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2022 and 2021.
EntergyEntergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of December 31, 2021$68.6 $13.1 $29.2 $7.2 $13.3 $5.8 
Provisions (a)11.0 8.2 0.4 0.2 0.9 1.3 
Write-offs(75.5)(21.8)(29.8)(7.4)(10.4)(6.1)
Recoveries21.5 6.7 7.9 2.2 3.1 1.6 
Balance as of June 30, 2022$25.6 $6.2 $7.7 $2.2 $6.9 $2.6 

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Notes to Financial Statements
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 
Provisions (b)25.9 5.5 11.7 1.7 4.6 2.4 
Write-offs(39.5)(2.8)(19.5)(8.8)(1.1)(7.3)
Recoveries5.0 1.4 1.9 1.2 0.2 0.3 
Balance as of June 30, 2021$109.1 $22.4 $39.8 $13.6 $21.1 $12.2 
(a)Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($8.9) million for Entergy, $3.9 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the COVID-19 orders issued by retail regulators.
(b)Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $8.7 million for Entergy, $0.8 million for Entergy Arkansas, $5.9 million for Entergy Louisiana, $0.7 million for Entergy New Orleans, and $1.3 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the COVID-19 orders issued by retail regulators.

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. 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 Mississippi)

Acquisitions

Sunflower Solar

In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity 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. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that

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Notes to Financial Statements
were then used to make an initial payment of $105 million for acquisition of the facility. A final payment will be made upon substantial completion of the facility and is currently expected in third quarter 2022.

Dispositions

Palisades

In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site. 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 issued an order approving the application in December 2021. Palisades was shut down in May 2022 and defueled in June 2022. The Palisades transaction closed in June 2022 for a purchase price of $1,000 (subject to adjustment for net liabilities and other amounts). The sale included the transfer of the Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter 2022. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $552 million and the disposition-date fair value of the asset retirement obligation was approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies.

________________

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


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

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

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of June 30, 2022, 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

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Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of each Registrants’ management, including its respective PEO and PFO, each Registrant evaluated changes in internal control over financial reporting that occurred during the quarter ended June 30, 2022 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.




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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

Net income increased $6.5 million primarily due to higher volume/weather and higher retail electric price, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Net income decreased $21 million primarily due to the reversal in 2021 of the remaining $38.8 million regulatory liability for the formula rate plan 2019 historical year netting adjustment, higher other operation and maintenance expenses, and higher depreciation and amortization expenses, partially offset by higher retail electric price and higher volume/weather.

Operating Revenues

Second Quarter 2022 Compared to Second Quarter 2021

Following is an analysis of the change in operating revenues comparing the second quarter 2022 to the second quarter 2021:
Amount
(In Millions)
2021 operating revenues$550.3 
Fuel, rider, and other revenues that do not significantly affect net income117.2 
Volume/weather18.1 
Retail electric price11.3 
2022 operating revenues$696.9 

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 the effect of more favorable weather on residential and commercial sales, partially offset by a decrease in weather-adjusted residential usage.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective January 2022. See Note 2 to the financial statements in the Form 10-K for further discussion of the 2021 formula rate plan filing.


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Total electric energy sales for Entergy Arkansas for the three months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential1,820 1,758 4 
Commercial1,383 1,373 1 
Industrial2,135 2,126 — 
Governmental56 55 2 
  Total retail 5,394 5,312 2 
Sales for resale:
  Associated companies450 525 (14)
  Non-associated companies2,010 1,700 18 
Total7,854 7,537 4 

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$1,133.7 
Fuel, rider, and other revenues that do not significantly affect net income61.8 
Retail electric price37.4 
Volume/weather15.0 
Return of unprotected excess accumulated deferred income taxes to customers8.0 
2022 operating revenues$1,255.9 

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 retail electric price variance is primarily due to increases in formula rate plan rates effective May 2021 and January 2022. See Note 2 to the financial statements in the Form 10-K for further discussion of the 2020 formula rate plan filing and the 2021 formula rate plan filing.

The volume/weather variance is primarily due to increases in commercial and industrial usage, partially offset by the effect of less favorable weather on residential sales. The increase in commercial usage was primarily due to an increase in customers and the effect of the COVID-19 pandemic on businesses in 2021. The increase in industrial usage was primarily due to an increase in demand from existing customers, primarily in the wood products and petroleum refining industries.


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The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a tax adjustment rider beginning in April 2018. For the six months ended June 30, 2021, $8 million was returned to customers. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Total electric energy sales for Entergy Arkansas for the six months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential3,912 3,943 (1)
Commercial2,690 2,635 2 
Industrial4,106 4,073 1 
Governmental111 110 1 
  Total retail 10,819 10,761 1 
Sales for resale:
  Associated companies936 1,122 (17)
  Non-associated companies3,401 3,731 (9)
Total15,156 15,614 (3)

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

Other Income Statement Variances

Second Quarter 2022 Compared to Second Quarter 2021

Other operation and maintenance expenses increased primarily due to:

•an increase of $5.1 million in non-nuclear generation expenses primarily due to a higher scope of work, including during plant outages, performed in 2022 as compared to 2021;
•an increase of $4.3 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to 2021; and
•an increase of $2.7 million in energy efficiency expenses due to the timing of recovery from customers, partially offset by lower energy efficiency costs.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Searcy Solar facility, which was placed in service in December 2021.

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

Noncontrolling interest reflects the earnings or losses attributable to the noncontrolling interest partner of the tax equity partnership for the Searcy Solar facility under HLBV accounting. Entergy Arkansas recorded a regulatory charge of $0.7 million in second quarter 2022 to defer the difference between the losses allocated to the tax equity partner under the HLBV method of accounting and the earnings/loss that would have been allocated to the tax equity partner under its respective ownership percentage in the partnership. See Note 1 to the financial statements in the Form 10-K for discussion of the HLBV method of accounting.


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Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Other operation and maintenance expenses increased primarily due to:

•an increase of $6.6 million in non-nuclear generation expenses primarily due to a higher scope of work, including during plant outages, performed in 2022 as compared to 2021;
•an increase of $6.5 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to 2021;
•an increase of $3.1 million in energy efficiency expenses due to the timing of recovery from customers and higher energy efficiency costs; and
•an increase of $2.8 million in customer service center support costs primarily due to higher contract costs.

The increase was partially offset by a decrease of $3.2 million in insurance expenses primarily due to higher nuclear insurance refunds received in 2022.

Taxes other than income taxes increased primarily due to increases in franchise taxes, employment 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 Searcy Solar facility, which was placed in service in December 2021.

Other regulatory charges (credits) - net includes the reversal in 2021 of the remaining $38.8 million regulatory liability for the 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements in the Form 10-K for discussion of the 2020 formula rate plan filing. In addition, Entergy Arkansas records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and nuclear decommissioning trust earnings plus asset retirement obligation related costs collected in revenue.

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

Interest expense increased primarily due to the issuance of $400 million of 3.35% Series mortgage bonds in March 2021 and the issuance of $200 million of 4.20% Series mortgage bonds in March 2022, partially offset by the repayment of $350 million of 3.75% Series mortgage bonds in February 2021.

Noncontrolling interest reflects the earnings or losses attributable to the noncontrolling interest partner of the tax equity partnership for the Searcy Solar facility under HLBV accounting. Entergy Arkansas recorded a regulatory charge of $2.2 million for the six months ended June 30, 2022 to defer the difference between the losses allocated to the tax equity partner under the HLBV method of accounting and the earnings/loss that would have been allocated to the tax equity partner under its respective ownership percentage in the partnership. See Note 1 to the financial statements in the Form 10-K for discussion of the HLBV method of accounting.

Income Taxes

The effective income tax rates were 21.9% for the second quarter 2022 and 22.3% for the six months ended June 30, 2022. The differences in the effective income tax rates for the second quarter 2022 and the six months ended June 30, 2022 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.

The effective income tax rate was 20.9% for the second quarter 2021. The difference in the effective income tax rate for the second quarter 2021 versus the federal statutory rate of 21% was primarily due to certain

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

The effective income tax rate was 18.7% for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See 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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
 20222021
 (In Thousands)
Cash and cash equivalents at beginning of period$12,915 $192,128 
Net cash provided by (used in):
Operating activities386,522 164,633 
Investing activities(376,810)(326,706)
Financing activities35,642 95,071 
Net increase (decrease) in cash and cash equivalents45,354 (67,002)
Cash and cash equivalents at end of period$58,269 $125,126 

Operating Activities

Net cash flow provided by operating activities increased $221.9 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•higher collections from customers;
•the timing of recovery of fuel and purchased power costs. See Note 2 to the financial statements herein for a discussion of fuel and purchased power cost recovery;
•a decrease in spending of $22 million on nuclear refueling outages in 2022;
•a decrease of $14.9 million in pension contributions in 2022. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” herein and in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding; and
•a decrease of $8.3 million in storm spending in 2022 primarily due to spending on Winter Storm Uri restoration efforts in 2021.

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


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Investing Activities

Net cash flow used in investing activities increased $50.1 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•an increase of $31.3 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration in 2022, partially offset by lower spending in 2022 on advanced metering infrastructure;
•an increase of $12.7 million in decommissioning trust fund investment activity; and
•an increase of $6.8 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.

Financing Activities

Net cash flow provided by financing activities decreased $59.4 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•the issuance of $400 million of 3.35% Series mortgage bonds in March 2021;
•money pool activity;
•the issuance of $90 million of 1.84% Series N notes payable in June 2021 by the Entergy Arkansas nuclear fuel company variable interest entity;
•$36 million in common equity distributions paid in 2022 in order to maintain Entergy Arkansas’s capital structure; and
•lower prepaid deposits of $24.3 million related to contributions-in-aid-of-construction generation interconnection agreements in 2022 as compared to 2021.

The decrease was partially offset by:

•the repayment, at maturity, of $350 million of 3.75% Series mortgage bonds in February 2021;
•the issuance of $200 million of 4.20% Series mortgage bonds in March 2022;
•the repayment, at maturity, of $45 million of 2.375% Series governmental bonds in January 2021; and
•net long-term borrowings of $7.2 million in 2022 compared to net repayments of long-term borrowings of $12.2 million in 2021 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility.

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 $139.9 million for the six months ended June 30, 2022. 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 Arkansas’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the issuance of long-term debt in 2022.
June 30,
2022		December 31,
2021
Debt to capital53.3 %52.6 %
Effect of subtracting cash(0.3 %)— %
Net debt to net capital53.0 %52.6 %

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 it provides 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.

The current annual amounts of Entergy Arkansas’s planned construction and other capital investments are as follows:

 202220232024
 (In Millions)
Planned construction and capital investment:  
Generation$205 $450 $980 
Transmission70 115 180 
Distribution285 305 420 
Utility Support130 100 65 
Total$690 $970 $1,645 

The updated capital plan for 2022-2024 reflects incremental capital investments for potential generation projects and increased capital project costs. The capital plan includes generation projects to modernize, decarbonize, and diversify Entergy Arkansas’s portfolio, such as West Memphis Solar and Driver Solar; investments in ANO 1 and 2; distribution and Utility support spending to improve reliability, resilience, and customer experience; transmission spending to drive reliability and resilience while also supporting renewables expansion; and other investments.

While Entergy Arkansas is still assessing the effect on its planned solar projects, the investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has exacerbated previously existing supply chain disruptions, which have negatively affected the timing and cost of completion of these projects.


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Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:
June 30,
2022		December 31,
2021		June 30,
2021		December 31,
2020
(In Thousands)
$6,216($139,904)$8,196$3,110

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

Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in June 2027. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 2023. The $150 million credit facility includes fronting commitments for the issuance of letters of credit against $5 million of the borrowing capacity of the facility. As of June 30, 2022, there were no cash borrowings and no letters of credit outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2022, $4.5 million in letters of credit were outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for further 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 2025.  As of June 30, 2022, $12 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 further discussion of the nuclear fuel company variable interest entity credit facility.

Walnut Bend Solar

As discussed in the Form 10-K, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In January 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Closing was expected to occur in 2022. The counter-party has notified Entergy Arkansas that it is terminating the project, though it is willing to consider an alternative for the site. Entergy Arkansas has disputed the right of termination. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2022.

West Memphis Solar

As discussed in the Form 10-K, in October 2021 the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In April 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Entergy Arkansas views the progress of the outreach to potential tax equity investors and the current status of the discussions as consistent with its expectations for the timeline for achieving a tax equity partnership. Closing had been expected to occur in 2023. The counter-party has notified Entergy Arkansas that it is seeking changes to certain terms of the build-own-transfer agreement, including both cost and schedule. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2023.

Driver Solar

In April 2022, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 250 MW Driver Solar facility is in the public interest and requested cost recovery through the formula rate plan rider. The acquisition of Driver Solar will be contingent upon receiving all necessary regulatory and Board approvals. The APSC established a procedural schedule with a hearing scheduled in June 2022, but the parties later agreed to waive the hearing and submit the matter to the APSC for a decision consistent with the filed record. The

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facility is expected to be in service by the end of 2024. Negotiations with the counter-party are expected to conclude in August 2022, and Entergy Arkansas has requested an APSC decision by August 31, 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 state and local rate regulation and fuel-cost recovery.  The following are updates to that discussion.

Retail Rates

2022 Formula Rate Plan Filing

In July 2022, Entergy Arkansas filed with the APSC its 2022 formula rate plan filing to set its formula rate for the 2023 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2023 and a netting adjustment for the historical year 2021. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2023 projected year is 7.40% resulting in a revenue deficiency of $104.8 million. The earned rate of return on common equity for the 2021 historical year was 8.38% resulting in a $15.2 million netting adjustment. The total proposed revenue change for the 2023 projected year and 2021 historical year netting adjustment is $119.9 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 $79.3 million.

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovered balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Opportunity Sales Proceeding

As discussed in the Form 10-K, 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 the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023. In June 2022, Entergy Arkansas filed a motion asserting that it is entitled to summary judgment because Entergy Arkansas’s position that the APSC’s order is pre-empted by the filed rate doctrine and violates the Dormant Commerce Clause is premised on facts that are not subject to genuine dispute. In July 2022, Arkansas Electric Energy Consumers, Inc., an industrial customer association, filed a motion to intervene and to hold Entergy Arkansas’s motion for summary judgment in abeyance pending a ruling on the motion to intervene. Entergy Arkansas filed a consolidated opposition to both motions.

Net Metering Legislation

As discussed in the Form 10-K, an Arkansas law was enacted effective July 2019 that, among other things, expands the definition of a “net metering customer” to include two additional types of customers: (1) customers that

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lease net metering facilities, subject to certain leasing arrangements, and (2) government entities or other entities exempt from state and federal income taxes that enter into a service contract for a net metering facility. The latter provision allows eligible entities, many of whom are small and large general service customers, to purchase renewable energy directly from third party providers and receive bill credits for these purchases. The APSC was given authority under this law to address certain matters, such as cost shifting and the appropriate compensation for net metered energy and initiated proceedings for this purpose. Because of the size and number of customers eligible under this new law, there is a risk of loss of load and the shifting of costs to customers. A hearing was held in December 2019, with utilities, including Entergy Arkansas, cooperatives, the Arkansas Attorney General, and industrial customers advocating the need for establishment of a reasonable rate structure that takes into account impacts to non-net metering customers; an additional hearing was conducted in February 2020 for purposes of public comment only. The APSC issued an order in June 2020, and in July 2020 several parties, including Entergy Arkansas, filed for rehearing on multiple grounds, including for the reasons that it imposes an unreasonable rate structure and allows facilities to net meter that do not meet the statutory definition of net metering facilities. After granting the rehearing requests, the APSC issued an order in September 2020 largely upholding its June 2020 order. In October 2020, Entergy Arkansas and several other parties filed an appeal of the APSC’s September 2020 order. 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 remained before the court. In May 2022 the court issued an order affirming the APSC’s decision in part and reversing in part. In June 2022 the APSC sought rehearing from the court with respect to the court’s ruling on a grid charge, which the court of appeals denied in July 2022. One of the cooperative appellants filed a further appeal to the Arkansas Supreme Court in July 2022.

Green Promise Renewable Tariff

As discussed in the Form 10-K, 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 designated to be available under this tariff is up to 200 MW. In May 2022 the APSC found Entergy Arkansas’s proposal for the tariff to be just and reasonable for an initial offering of 100 MW of solar capacity, and in June 2022 the APSC approved Entergy Arkansas’s compliance tariff filing.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of June 30, 2022, Entergy Arkansas had a regulatory asset of $36.6 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 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. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

New Accounting Pronouncements

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


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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$696,939 $550,274 $1,255,895 $1,133,660 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale202,795 74,556 289,020 200,737 
Purchased power50,209 61,448 107,680 131,669 
Nuclear refueling outage expenses14,210 13,535 28,280 26,182 
Other operation and maintenance187,319 173,098 344,576 328,006 
Decommissioning20,428 19,280 40,557 38,280 
Taxes other than income taxes32,072 30,106 65,274 59,849 
Depreciation and amortization96,548 90,276 192,158 178,555 
Other regulatory charges (credits) - net(21,518)(22,170)(42,060)(59,637)
TOTAL582,063 440,129 1,025,485 903,641 
OPERATING INCOME114,876 110,145 230,410 230,019 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction3,920 3,608 6,975 6,601 
Interest and investment income (loss)2,840 (2,739)9,160 25,148 
Miscellaneous - net(4,892)(5,372)(10,284)(11,163)
TOTAL1,868 (4,503)5,851 20,586 
INTEREST EXPENSE
Interest expense37,452 35,624 73,499 69,410 
Allowance for borrowed funds used during construction(1,558)(1,572)(2,772)(2,862)
TOTAL35,894 34,052 70,727 66,548 
INCOME BEFORE INCOME TAXES80,850 71,590 165,534 184,057 
Income taxes17,740 14,997 36,857 34,427 
NET INCOME63,110 56,593 128,677 149,630 
Net loss attributable to noncontrolling interest(529)— (1,916)— 
EARNINGS APPLICABLE TO MEMBER'S EQUITY$63,639 $56,593 $130,593 $149,630 
See Notes to Financial Statements.












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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income$128,677 $149,630 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization268,699 252,537 
Deferred income taxes, investment tax credits, and non-current taxes accrued27,814 50,780 
Changes in assets and liabilities:
Receivables(95,608)(86,447)
Fuel inventory7,316 12,996 
Accounts payable34,321 27,920 
Taxes accrued14,824 (6,529)
Interest accrued1,585 (2,490)
Deferred fuel costs(2,384)(74,857)
Other working capital accounts13,458 (36,703)
Provisions for estimated losses(4,119)(6,122)
Other regulatory assets(30,484)32,837 
Other regulatory liabilities(267,437)17,776 
Pension and other postretirement liabilities(31,762)(46,940)
Other assets and liabilities321,622 (119,755)
Net cash flow provided by operating activities386,522 164,633 
INVESTING ACTIVITIES
Construction expenditures(351,907)(322,044)
Allowance for equity funds used during construction6,975 6,601 
Nuclear fuel purchases(53,256)(25,466)
Proceeds from sale of nuclear fuel37,198 16,239 
Proceeds from nuclear decommissioning trust fund sales101,428 227,807 
Investment in nuclear decommissioning trust funds(111,032)(224,757)
Changes in money pool receivable - net(6,216)(5,086)
Net cash flow used in investing activities(376,810)(326,706)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt223,882 694,137 
Retirement of long-term debt(7,511)(618,511)
Distributions to noncontrolling interest(190)— 
Change in money pool payable - net(139,904)— 
Common equity distributions paid(36,000)— 
Other(4,635)19,445 
Net cash flow provided by financing activities35,642 95,071 
Net increase (decrease) in cash and cash equivalents45,354 (67,002)
Cash and cash equivalents at beginning of period12,915 192,128 
Cash and cash equivalents at end of period$58,269 $125,126 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: 
Cash paid during the period for:
Interest - net of amount capitalized$70,803 $70,700 
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$102 $8,155 
Temporary cash investments58,167 4,760 
Total cash and cash equivalents58,269 12,915 
Accounts receivable:
Customer137,481 154,412 
Allowance for doubtful accounts(6,206)(13,072)
Associated companies47,582 29,587 
Other113,657 51,064 
Accrued unbilled revenues132,964 101,663 
Total accounts receivable425,478 323,654 
Deferred fuel costs111,147 108,862 
Fuel inventory - at average cost43,576 50,892 
Materials and supplies - at average cost268,184 247,980 
Deferred nuclear refueling outage costs38,142 65,318 
Prepayments and other22,011 14,863 
TOTAL966,807 824,484 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,194,815 1,438,416 
Other790 947 
TOTAL1,195,605 1,439,363 
UTILITY PLANT
Electric13,740,737 13,578,297 
Construction work in progress371,705 241,127 
Nuclear fuel140,168 182,055 
TOTAL UTILITY PLANT14,252,610 14,001,479 
Less - accumulated depreciation and amortization5,608,711 5,472,296 
UTILITY PLANT - NET8,643,899 8,529,183 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets1,720,162 1,689,678 
Deferred fuel costs68,850 68,751 
Other20,467 13,660 
TOTAL1,809,479 1,772,089 
TOTAL ASSETS$12,615,790 $12,565,119 
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$250,000 $— 
Accounts payable:
Associated companies67,262 217,310 
Other278,178 190,476 
Customer deposits97,336 92,511 
Taxes accrued104,414 89,590 
Interest accrued18,693 17,108 
Other47,940 38,901 
TOTAL863,823 645,896 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued1,459,515 1,416,201 
Accumulated deferred investment tax credits28,698 29,299 
Regulatory liability for income taxes - net422,449 431,655 
Other regulatory liabilities485,083 743,314 
Decommissioning1,430,967 1,390,410 
Accumulated provisions72,965 77,084 
Pension and other postretirement liabilities153,960 185,789 
Long-term debt3,925,929 3,958,862 
Other104,059 110,754 
TOTAL8,083,625 8,343,368 
Commitments and Contingencies
EQUITY
Member's equity3,637,338 3,542,745 
Noncontrolling interest31,004 33,110 
TOTAL3,668,342 3,575,855 
TOTAL LIABILITIES AND EQUITY$12,615,790 $12,565,119 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
Noncontrolling InterestMember's EquityTotal
(In Thousands)
Balance at December 31, 2020$— $3,276,169 $3,276,169 
Net income— 93,037 93,037 
Balance at March 31, 2021— 3,369,206 3,369,206 
Net income— 56,593 56,593 
Balance at June 30, 2021$— $3,425,799 $3,425,799 
Balance at December 31, 2021$33,110 $3,542,745 $3,575,855 
Net income (loss)(1,387)66,954 65,567 
Balance at March 31, 202231,723 3,609,699 3,641,422 
Net income (loss)(529)63,639 63,110 
Common equity distributions— (36,000)(36,000)
Distributions to noncontrolling interest(190)— (190)
Balance at June 30, 2022$31,004 $3,637,338 $3,668,342 
See Notes to Financial Statements.

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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

Net income increased $172.7 million primarily due to the net effects of Entergy Louisiana’s storm cost securitization, including a $290 million reduction in income tax expense, partially offset by a $224.4 million ($165.4 million net-of-tax) regulatory charge to reflect its obligation to share the benefits of the securitization with customers. Also contributing to the net income increase was higher volume/weather and higher retail price, partially offset by higher other operation and maintenance expenses. See Note 2 to the financial statements herein for further discussion of the securitization.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Net income increased $157 million primarily due to the net effects of Entergy Louisiana’s storm cost securitization, including a $290 million reduction in income tax expense, partially offset by a $224.4 million ($165.4 million net-of-tax) regulatory charge to reflect its obligation to share the benefits of the securitization with customers. Also contributing to the net income increase was higher volume/weather and higher retail price, partially offset by higher other operation and maintenance expenses. See Note 2 to the financial statements herein for further discussion of the securitization.

Operating Revenues

Second Quarter 2022 Compared to Second Quarter 2021

Following is an analysis of the change in operating revenues comparing the second quarter 2022 to the second quarter 2021:
Amount
(In Millions)
2021 operating revenues$1,267.6 
Fuel, rider, and other revenues that do not significantly affect net income135.4 
Volume/weather56.8 
Storm restoration carrying costs37.5 
Retail electric price18.5 
2022 operating revenues$1,515.8 

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

The volume/weather variance is primarily due to an increase of 1,180 GWh, or 9%, in electricity usage across all customer classes, including the effect of more favorable weather on residential and commercial sales. The increase in industrial usage was primarily due to an increase in demand from expansion projects, primarily in the

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chemicals, petroleum refining, and transportation industries, an increase in demand from cogeneration customers, and an increase in demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns.

Storm restoration carrying costs represent the equity component of storm restoration carrying costs, recorded in second quarter 2022, recognized as part of the securitization of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida restoration costs in May 2022. See Note 2 to the financial statements herein for a discussion of the securitization.

The retail electric price variance is primarily due to an increase in formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective September 2021. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan proceedings.

Total electric energy sales for Entergy Louisiana for the three months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential3,824 3,399 13 
Commercial2,879 2,641 9 
Industrial8,148 7,636 7 
Governmental208 203 2 
  Total retail 15,059 13,879 9 
Sales for resale:
  Associated companies1,315 1,167 13 
  Non-associated companies467 552 (15)
Total16,841 15,598 8 

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$2,375.2 
Fuel, rider, and other revenues that do not significantly affect net income288.8 
Volume/weather44.5 
Storm restoration carrying costs37.5 
Retail electric price35.8 
2022 operating revenues$2,781.8 

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.

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The volume/weather variance is primarily due to the effect of more favorable weather on residential sales and an increase in commercial and industrial usage, partially offset by a decrease in weather-adjusted residential usage. The increase in industrial usage was primarily due to an increase in demand from expansion projects, primarily in the chemicals, petroleum refining, and transportation industries, an increase in demand from cogeneration customers, and an increase in demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns. The increased usage from these industrial and commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

Storm restoration carrying costs represent the equity component of storm restoration carrying costs, recorded in second quarter 2022, recognized as part of the securitization of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida restoration costs in May 2022. See Note 2 to the financial statements herein for a discussion of the securitization.

The retail electric price variance is primarily due to an increase in formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective September 2021. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan proceedings.

Total electric energy sales for Entergy Louisiana for the six months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential6,893 6,596 5 
Commercial5,300 5,036 5 
Industrial15,754 14,844 6 
Governmental399 399 — 
  Total retail 28,346 26,875 5 
Sales for resale:
  Associated companies2,656 2,126 25 
  Non-associated companies1,323 938 41 
Total32,325 29,939 8 

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

Other Income Statement Variances

Second Quarter 2022 Compared to Second Quarter 2021

Other operation and maintenance expenses increased primarily due to:

•an increase of $7.3 million in power delivery expenses primarily due to higher reliability costs and higher safety and training costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;
•an increase of $3.9 million in bad debt expense primarily due to the deferral in 2021 of bad debt expense 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;

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•an increase of $2.1 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to prior year; and
•an increase of $2 million in customer service center support costs primarily due to higher contract costs.

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.

Other regulatory charges (credits) - net includes a regulatory charge of $224 million, recorded in second quarter 2022, to reflect Entergy Louisiana’s obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued in the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the financial statements herein for discussion of the securitization.

Other income decreased primarily due to a $31.6 million charge for the LURC’s 1% beneficial interest in the storm trust established as part of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization. The decrease was partially offset by:

•an increase of $11.3 million in affiliated dividend income resulting from the storm trust’s investment of securitization proceeds in affiliated preferred membership interests, partially offset by the liquidation of Entergy Louisiana’s investment in affiliated preferred membership interests acquired in connection with previous securitizations of storm restoration costs; and
•an increase of $5.6 million due to the recognition of storm restoration carrying costs, primarily related to Hurricane Ida.

See Note 2 to the financial statements herein for discussion of the securitization.

Interest expense increased primarily due to the $1.2 billion unsecured term loan proceeds received in January 2022 and the issuance of $1 billion of 0.95% Series mortgage bonds in October 2021.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Other operation and maintenance expenses increased primarily due to:

•an increase of $16.6 million in power delivery expenses primarily due to higher reliability costs and higher safety and training costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;
•an increase of $4.7 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to prior year, partially offset by lower spending in 2022 on sanitation and social distancing protocols as a result of the COVID-19 pandemic;
•an increase of $4.5 million in customer service center support costs primarily due to higher contract costs;
•an increase of $3.0 million in loss provisions; and
•an increase of $2.9 million in bad debt expense primarily due to the deferral in 2021 of bad debt expense 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.

The increase was partially offset by a decrease of $2.7 million in non-nuclear generation expenses primarily due to a lower scope of work performed in 2022 as compared to the same period in 2021.

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

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

Other regulatory charges (credits) - net includes a regulatory charge of $224 million, recorded in second quarter 2022, to reflect Entergy Louisiana’s obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued in the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the financial statements herein for discussion of the securitization.

Other income decreased primarily due to:

•a $31.6 million charge for the LURC’s 1% beneficial interest in the storm trust established as part of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization; and
•changes in decommissioning trust fund activity, including portfolio rebalancing of the Waterford 3 decommissioning trust fund in the first quarter of 2021 partially offset by portfolio rebalancing of the River Bend decommissioning trust fund in the second quarter of 2022.

The decrease was partially offset by:

•an increase of $11.3 million in affiliated dividend income resulting from the storm trust’s investment of securitization proceeds in affiliated preferred membership interests, partially offset by the liquidation of Entergy Louisiana’s investment in affiliated preferred membership interests acquired in connection with previous securitizations of storm restoration costs; and
•an increase of $10.5 million due to the recognition of storm restoration carrying costs, primarily related to Hurricane Ida.

See Note 2 to the financial statements herein for discussion of the securitization.

Interest expense increased primarily due to:

•the issuances of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;
•the $1.2 billion unsecured term loan proceeds received in January 2022; and
•the issuance of $1 billion of 0.95% Series mortgage bonds in October 2021.

The increase was partially offset by the repayment of $200 million of 4.8% Series mortgage bonds in May 2021.

Income Taxes

The effective income tax rate was (3,258.7%) for the second quarter 2022. The difference in the effective income tax rate for the second quarter 2022 versus the federal statutory rate of 21% was primarily due to the reduction in income tax expense as a result of the securitization of Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida storm costs pursuant to Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, certain book and tax differences related to utility plant items, the amortization of excess accumulated deferred income taxes, the amortization of investment tax credits, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Notes 2 and 10 to the financial statements herein for a discussion of the securitization under Act 293. 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 (144.7%) for the six months ended June 30, 2022. The difference in the effective income tax rate for the six months ended June 30, 2022 versus the federal statutory rate of 21% was primarily due to the reduction in income tax expense as a result of the securitization of Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida storm costs pursuant to Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, certain book and tax differences related to utility plant items, and the amortization of excess accumulated deferred income taxes, partially offset by state income taxes. See Notes 2 and 10 to the financial statements herein for a discussion of the securitization under Act 293. 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 15.4% for the second quarter 2021 and 17.1% for the six months ended June 30, 2021. The differences in the effective income tax rates for the second quarter 2021 and the six months ended June 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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Cash and cash equivalents at beginning of period$18,573 $728,020 
Net cash provided by (used in):
    Operating activities206,713 519,407 
    Investing activities(3,653,859)(1,836,723)
    Financing activities3,494,744 796,170 
Net increase (decrease) in cash and cash equivalents47,598 (521,146)
Cash and cash equivalents at end of period$66,171 $206,874 

Operating Activities

Net cash flow provided by operating activities decreased by $312.7 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•increased fuel costs. See Note 2 to the financial statements herein for a discussion of fuel and purchased power cost recovery;
•an increase of approximately $107 million in storm spending, primarily due to Hurricane Ida restoration efforts in 2022, partially offset by Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts in 2021; and
•the timing of payments to vendors.


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The decrease was partially offset by higher collections from customers and a decrease of $26 million in pension contributions in 2022. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” herein and in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

Investing Activities

Net cash flow used in investing activities increased $1,817.1 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•an increase in investments in affiliates due to the $3,164 million purchase by the storm trust of preferred membership interests issued by an Entergy affiliate, partially offset by the $1,391 million redemption of preferred membership interests. See Note 2 to the financial statements herein for a discussion of the securitization;
•an increase of $290.1 million in net payments to storm reserve escrow accounts;
•an increase of $99.3 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration in 2022 and increased investment in the reliability and infrastructure of Entergy Louisiana’s distribution system, partially offset by lower spending in 2022 on advanced metering infrastructure;
•an increase of $45.5 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2022 and higher capital expenditures for storm restoration in 2022;
•an increase of $15.5 million in information technology capital expenditures primarily due to increased spending on various technology projects in 2022; and
•an increase of $10.7 million in non-nuclear generation construction expenditures primarily due to a higher scope of work on projects performed in 2022 as compared to 2021.

The increase was partially offset by:

•a decrease of $240.3 million in transmission construction expenditures primarily due to higher capital expenditures for storm restoration in 2021. The decrease in storm restoration spending is primarily due to Hurricane Laura restoration efforts;
•money pool activity;
•a decrease of $30.7 million in nuclear decommissioning trust fund activity as a result of a lump sum contribution in 2021 for amounts collected over a 17-month period. See Note 2 to the financial statements in the Form 10-K for a discussion of nuclear decommissioning expense recovery; and
•a decrease of $23.6 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.

Decreases in Entergy Louisiana’s receivables from the money pool are a source of cash flow, and Entergy Louisiana’s receivable from the money pool decreased $7.2 million for the six months ended June 30, 2022 compared to increasing by $90.2 million for the six months ended June 30, 2021. 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 $2,698.6 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•proceeds from securitization of $3.2 billion received by the storm trust;

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•a capital contribution of $1 billion received indirectly from Entergy Corporation in May 2022 to finance the establishment of the storm escrow account for Hurricane Ida costs;
•the repayment, at maturity, of $200 million of 4.80% Series mortgage bonds in May 2021; and
•the repayment, at maturity, of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notes in February 2021.

The increase was partially offset by:

•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 repayment in May 2022 of $435 million, a portion of the outstanding principal, of 0.62% Series mortgage bonds due November 2023;
•net repayments of $125 million in 2022 on Entergy Louisiana’s revolving credit facility;
•net long-term borrowings of $8.1 million in 2022 compared to net long-term borrowings of $68.5 million in 2021 on the nuclear fuel company variable interest entities’ credit facilities; and
•$125 million in common equity distributions in 2022 to return to Entergy Corporation the $125 million capital contribution received in December 2021 to assist in paying for costs associated with Hurricane Ida.

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. See Note 2 to the financial statements herein for a discussion of the securitization.

Capital Structure

Entergy Louisiana’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy Louisiana is primarily due to the $1.0 billion capital contribution received indirectly from Entergy Corporation in May 2022.
June 30,
 2022		December 31,
2021
Debt to capital52.1 %57.2 %
Effect of subtracting cash(0.2 %)0.0 %
Net debt to net capital51.9 %57.2 %

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 Louisiana 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 Louisiana’s financial condition. Entergy Louisiana 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 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.

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.


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Following are the amounts of Entergy Louisiana’s planned construction and other capital investments.

 202220232024
 (In Millions)
Planned construction and capital investment:  
Generation$395 $380 $580 
Transmission545 380 520 
Distribution475 460 550 
Utility Support200 140 110 
Total$1,615 $1,360 $1,760 

The updated capital plan for 2022-2024 reflects incremental capital investments for accelerated resilience spending and increased capital project costs. The capital plan includes specific investments such as generation projects to modernize, decarbonize, and diversify Entergy Louisiana’s portfolio, including St. Jacques Louisiana Solar; investments in River Bend and Waterford 3; distribution and Utility support spending to improve reliability, resilience, and customer experience; transmission spending to drive reliability and resilience while also supporting renewables expansion; and other investments.

While Entergy Louisiana is still assessing the effect on its planned solar projects, the investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has exacerbated previously existing supply chain disruptions, which have negatively affected the timing and cost of completion of these projects.

Entergy Louisiana’s receivables from the money pool were as follows:

June 30,
 2022		December 31,
2021		June 30,
 2021		December 31,
2020
(In Thousands)
$7,377$14,539$103,651$13,426

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 2027.  The credit facility includes fronting commitments for the issuance of letters of credit against $15 million of the borrowing capacity of the facility. As of June 30, 2022, 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 June 30, 2022, $70 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 2025.  As of June 30, 2022, $20 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of June 30, 2022, $70.4 million in loans were outstanding under the credit facility for the Entergy Louisiana Waterford nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facilities.

Entergy Louisiana has $290.1 million in its storm reserve escrow account at June 30, 2022.


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2021 Solar Certification and the Geaux Green Option

As discussed in the Form 10-K, in November 2021, Entergy Louisiana filed an application with the LPSC seeking certification of and approval for the addition of four new solar photovoltaic resources with a combined nameplate capacity of 475 megawatts (the 2021 Solar Portfolio) and the implementation of a new green tariff, the Geaux Green Option (Rider GGO). The LPSC has established a procedural schedule that is expected to result in an LPSC decision by the end of 2022. In March 2022 direct testimony from Walmart, the Louisiana Energy Users Group (LEUG) and the LPSC staff was filed. Each party recommended that the LPSC approve the resources proposed in Entergy Louisiana’s application, and the LPSC staff witness indicated that the process through which Entergy Louisiana solicited or obtained the proposals for the resources complies with applicable LPSC orders. LPSC staff and LEUG’s witnesses made recommendations to modify the proposed Rider GGO and Entergy Louisiana’s proposed rate relief. In April 2022, LPSC staff and LEUG filed cross-answering testimony concerning the other party’s proposed modifications to Rider GGO and the proposed rate recovery. Entergy Louisiana filed rebuttal testimony in June 2022. Settlement talks are ongoing, and a hearing is set for mid-August 2022.

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

As discussed in the Form 10-K, 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 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 additional outages.

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 for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were 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 sought an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana requested that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was 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 August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage 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, subject to a subsequent prudence review.


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After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, Entergy Louisiana reclassified $1.942 billion from utility plant to other regulatory assets.

In May 2022 the securitization financing closed, resulting in the issuance of $3.194 billion principal amount of bonds by Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA), a political subdivision of the State of Louisiana. The securitization was authorized pursuant to the Louisiana Utilities Restoration Corporation Act, Part VIII of Chapter 9 of Title 45 of the Louisiana Revised Statutes, as supplemented by Act 293 of the Louisiana legislature approved in 2021. The LCDA loaned the proceeds to the LURC. Pursuant to Act 293, the LURC contributed the net bond proceeds to a State legislatively authorized and LURC-sponsored trust, Restoration Law Trust I (the storm trust).

Pursuant to Act 293, the net proceeds of the bonds were used by the storm trust to purchase 31,635,718.7221 Class A preferred, non-voting membership interest units (the preferred interests) issued by Entergy Finance Company, LLC, a majority-owned indirect subsidiary of Entergy. Entergy Finance Company is required to make annual distributions (dividends) commencing on December 15, 2022 on the preferred interests issued to the storm trust. These annual dividends received by the storm trust will be distributed to Entergy Louisiana and the LURC, as beneficiaries of the storm trust. Specifically, 1% of the annual dividends received by the storm trust will be distributed to the LURC, for the benefit of customers, and 99% will be distributed to Entergy Louisiana, net of storm trust expenses. The preferred interests have a stated annual cumulative cash dividend rate of 7% and a liquidation price of $100 per unit. The terms of the preferred interests include certain financial covenants to which Entergy Finance Company is subject.

Entergy and Entergy Louisiana do not report the bonds issued by the LCDA on their balance sheets because the bonds are the obligation of the LCDA. The bonds are secured by system restoration property, which is the right granted by law to the LURC to collect a system restoration charge from customers. The system restoration charge is adjusted at least semi-annually to ensure that it is sufficient to service the bonds. Entergy Louisiana collects the system restoration charge on behalf of the LURC and remits the collections to the bond indenture trustee. Entergy Louisiana began collecting the system restoration charge effective with the first billing cycle of June 2022 and the system restoration charge is expected to remain in place up to 15 years. Entergy and Entergy Louisiana do not report the collections as revenue because Entergy Louisiana is merely acting as a billing and collection agent for the LCDA and the LURC. In the remote possibility that the system restoration charge, as well as any funds in the excess subaccount and funds in the debt service reserve account, are insufficient to service the bonds resulting in a payment default, the storm trust is required to liquidate Entergy Finance Company preferred interests in an amount equal to what would be required to cure the default. The estimated value of this indirect guarantee is immaterial.

From the proceeds from the issuance of the preferred membership interests, Entergy Finance Company distributed $1.4 billion to its parent, Entergy Holdings Company, LLC. Subsequently, Entergy Holdings Company liquidated, distributing the $1.4 billion it received from Entergy Finance Company to Entergy Louisiana as holder of 6,843,780.24 units of Class A, 4,126,940.15 units of Class B, and 2,935,152.69 units of Class C preferred membership interests. Entergy Louisiana had acquired these preferred membership interests with proceeds from previous securitizations of storm restoration costs. Entergy Finance Company loaned the remaining $1.7 billion from the preferred membership interests proceeds to Entergy which used the cash to redeem $650 million of 4.00% Series senior notes due July 2022 and indirectly contributed $1 billion to Entergy Louisiana as a capital contribution.

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Entergy Louisiana used the $1 billion capital contribution to fund its Hurricane Ida escrow account and subsequently withdrew the $1 billion from the escrow account. With a portion of the $1 billion withdrawn from the escrow account and the $1.4 billion from the Entergy Holdings Company liquidation, Entergy Louisiana deposited $290 million in a restricted escrow account as a storm damage reserve for future storms, used $1.2 billion to repay its unsecured term loan due June 2023, and used $435 million to redeem a portion of its 0.62% Series mortgage bonds due November 2023.

As discussed in Note 10 to the financial statements herein, the securitization resulted in recognition of a reduction of income tax expense of approximately $290 million by Entergy Louisiana. Entergy’s recognition of reduced income tax expense was offset by other tax charges resulting in a net reduction of income tax expense of $283 million. In recognition of obligations related to an LPSC ancillary order issued as part of the securitization regulatory proceeding, Entergy Louisiana recorded a $224 million ($165 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to share the benefits of the securitization with customers.

As discussed in Note 12 to the financial statements herein, Entergy Louisiana consolidates the storm trust as a variable interest entity and the LURC’s 1% beneficial interest is shown as noncontrolling interest in the financial statements. In second quarter 2022, Entergy Louisiana recorded a charge of $31.6 million in other income to reflect the LURC’s beneficial interest in the trust.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs of $57 million through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow account from which funds were withdrawn to finance costs associated with Hurricane Ida restoration. In June 2022, 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. A procedural schedule has been established with a hearing in December 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 state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

Retail Rates - Electric

2021 Formula Rate Plan Filing

In May 2022, Entergy Louisiana filed its formula rate plan evaluation report for its 2021 calendar year operations. The 2021 test year evaluation report produced an earned return on common equity of 8.33%, with a base formula rate plan revenue increase of $65.3 million. Other increases in formula rate plan revenue driven by reductions in Tax Cut and Jobs Act credits and additions to transmission and distribution plant in service reflected

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through the transmission recovery mechanism and distribution recovery mechanism are partly offset by an increase in net MISO revenues, leading to a net increase in formula rate plan revenue of $152.9 million. 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 $86 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $66.9 million. Subject to refund and LPSC review, the resulting changes will be effective for bills rendered during the first billing cycle of September 2022.

Fuel and purchased power recovery

As discussed in the Form 10-K, 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. In April 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s fuel adjustment clause charges in February 2021 that did not recommend any financial disallowances, but included several prospective recommendations. Responsive testimony was filed by one intervenor and the parties agreed to suspend any procedural schedule and move toward settlement discussions to close the matter.

In May 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s purchased gas adjustment charges in February 2021 that did not propose any financial disallowances. The LPSC staff and Entergy Louisiana have agreed to suspend any procedural schedule and move toward settlement discussions to close the matter.

To mitigate high electric bills, primarily driven by high summer usage and elevated gas prices, Entergy Louisiana has deferred approximately $135 million of fuel expense incurred in April, May, and June 2022 (as reflected in June, July, and August 2022 bills). Deferrals from April and May 2022 are expected to be recovered in the last four months of 2022 and June 2022 deferrals will be included in the over/under calculation of the fuel adjustment clause.

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. 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 June 30, 2022, Entergy Louisiana had a regulatory asset of $47.8 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. 


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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. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

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 Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$1,497,942 $1,254,579 $2,735,179 $2,334,242 
Natural gas17,843 13,019 46,578 41,000 
TOTAL1,515,785 1,267,598 2,781,757 2,375,242 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale253,505 355,362 615,579 500,596 
Purchased power420,549 186,596 596,746 396,557 
Nuclear refueling outage expenses10,029 12,193 21,976 25,475 
Other operation and maintenance293,746 275,599 547,747 513,082 
Decommissioning17,911 17,035 35,599 33,858 
Taxes other than income taxes58,566 51,968 120,181 104,452 
Depreciation and amortization171,719 163,061 340,802 323,874 
Other regulatory charges (credits) - net203,461 (21,617)182,564 9,480 
TOTAL1,429,486 1,040,197 2,461,194 1,907,374 
OPERATING INCOME86,299 227,401 320,563 467,868 
OTHER INCOME
Allowance for equity funds used during construction2,859 6,835 9,585 12,936 
Interest and investment income(68,382)27,559 (84,380)68,175 
Interest and investment income - affiliated43,203 31,898 75,101 63,797 
Miscellaneous - net36,986 (36,033)52,503 (70,671)
TOTAL14,666 30,259 52,809 74,237 
INTEREST EXPENSE
Interest expense92,755 90,630 186,539 173,436 
Allowance for borrowed funds used during construction(1,218)(3,068)(4,244)(5,827)
TOTAL91,537 87,562 182,295 167,609 
INCOME BEFORE INCOME TAXES9,428 170,098 191,077 374,496 
Income taxes(307,231)26,171 (276,442)63,943 
NET INCOME316,659 143,927 467,519 310,553 
Noncontrolling interest258 — 258 — 
EARNINGS APPLICABLE TO MEMBER'S EQUITY$316,401 $143,927 $467,261 $310,553 
See Notes to Financial Statements.


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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
Net Income$316,659 $143,927 $467,519 $310,553 
Other comprehensive income (loss)
Pension and other postretirement liabilities (net of tax expense (benefit) of ($181), $208, ($407), and $64)
(491)588 (1,104)181 
Other comprehensive income (loss)(491)588 (1,104)181 
Comprehensive Income316,168 144,515 466,415 310,734 
Noncontrolling interest258 — 258 — 
Comprehensive Income Applicable to Member’s Equity$315,910 $144,515 $466,157 $310,734 
See Notes to Financial Statements.



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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income$467,519 $310,553 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization414,975 402,106 
Deferred income taxes, investment tax credits, and non-current taxes accrued(198,525)90,537 
Changes in working capital:
Receivables(114,357)(66,281)
Fuel inventory(183)(1,240)
Accounts payable(20,380)25,685 
Taxes accrued(1,686)54,850 
Interest accrued(3,263)2,162 
Deferred fuel costs(367,321)(96,429)
Other working capital accounts(107,409)(36,605)
Changes in provisions for estimated losses294,067 (291)
Changes in other regulatory assets859,908 (124,939)
Changes in other regulatory liabilities(40,596)87,823 
Effect of securitization on regulatory asset(1,190,338)— 
Changes in pension and other postretirement liabilities(17,123)(43,936)
Other231,425 (84,588)
Net cash flow provided by operating activities206,713 519,407 
INVESTING ACTIVITIES
Construction expenditures(1,565,051)(1,655,993)
Allowance for equity funds used during construction9,585 12,936 
Nuclear fuel purchases(77,561)(63,479)
Proceeds from the sale of nuclear fuel37,634 — 
Receipts from storm reserve escrow account1,000,217 — 
Payments to storm reserve escrow account(1,290,282)— 
Purchase of preferred membership interests of affiliate (3,163,572)— 
Redemption of preferred membership interests of affiliate1,390,587 — 
Changes to securitization account— (956)
Proceeds from nuclear decommissioning trust fund sales411,600 459,326 
Investment in nuclear decommissioning trust funds(419,873)(498,332)
Changes in money pool receivable - net7,162 (90,225)
Litigation proceeds from settlement agreement5,695 — 
Net cash flow used in investing activities(3,653,859)(1,836,723)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,777,192 2,097,214 
Retirement of long-term debt(2,327,116)(1,296,875)
Proceeds from trust related to securitization3,163,572 — 
Capital contribution from parent1,000,000 — 
Common equity distributions paid(125,000)— 
Other6,096 (4,169)
Net cash flow provided by financing activities3,494,744 796,170 
Net increase (decrease) in cash and cash equivalents47,598 (521,146)
Cash and cash equivalents at beginning of period18,573 728,020 
Cash and cash equivalents at end of period$66,171 $206,874 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$183,686 $165,480 
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$454 $195 
Temporary cash investments65,717 18,378 
Total cash and cash equivalents66,171 18,573 
Accounts receivable:
Customer373,359 355,265 
Allowance for doubtful accounts(7,654)(29,231)
Associated companies113,492 96,539 
Other48,814 36,674 
Accrued unbilled revenues213,199 174,768 
Total accounts receivable741,210 634,015 
Deferred fuel costs412,695 45,374 
Fuel inventory43,141 42,958 
Materials and supplies - at average cost516,412 485,325 
Deferred nuclear refueling outage costs100,751 39,582 
Prepayments and other84,504 44,187 
TOTAL1,964,884 1,310,014 
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests3,163,572 1,390,587 
Decommissioning trust funds1,756,483 2,114,523 
Storm reserve escrow account290,065 — 
Non-utility property - at cost (less accumulated depreciation)339,975 337,247 
Other13,992 13,744 
TOTAL5,564,087 3,856,101 
UTILITY PLANT
Electric26,976,504 28,055,038 
Natural gas292,065 285,006 
Construction work in progress785,737 847,924 
Nuclear fuel184,700 209,418 
TOTAL UTILITY PLANT28,239,006 29,397,386 
Less - accumulated depreciation and amortization10,065,760 9,860,252 
UTILITY PLANT - NET18,173,246 19,537,134 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets1,916,758 2,776,666 
Deferred fuel costs168,122 168,122 
Other40,203 27,801 
TOTAL2,125,083 2,972,589 
TOTAL ASSETS$27,827,300 $27,675,838 
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$200,000 $200,000 
Accounts payable:
Associated companies123,940 183,172 
Other882,132 1,481,902 
Customer deposits156,467 150,697 
Taxes accrued62,562 64,248 
Interest accrued89,789 93,052 
Current portion of unprotected excess accumulated deferred income taxes6,073 24,291 
Other88,718 68,995 
TOTAL1,609,681 2,266,357 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued2,235,221 2,433,854 
Accumulated deferred investment tax credits100,228 102,588 
Regulatory liability for income taxes - net303,290 313,693 
Other regulatory liabilities1,030,622 1,042,597 
Decommissioning1,694,679 1,653,198 
Accumulated provisions318,557 24,490 
Pension and other postretirement liabilities511,136 528,213 
Long-term debt10,169,840 10,714,346 
Other300,449 415,930 
TOTAL16,664,022 17,228,909 
Commitments and Contingencies
EQUITY
Member's equity9,514,529 8,172,294 
Accumulated other comprehensive income7,174 8,278 
Noncontrolling interest31,894 — 
TOTAL9,553,597 8,180,572 
TOTAL LIABILITIES AND EQUITY$27,827,300 $27,675,838 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
Noncontrolling InterestMember’s
Equity		Accumulated
Other
Comprehensive
Income		Total
(In Thousands)
Balance at December 31, 2020$— $7,453,361 $4,327 $7,457,688 
Net income— 166,626 — 166,626 
Other comprehensive loss— — (407)(407)
Other— (16)— (16)
Balance at March 31, 2021— 7,619,971 3,920 7,623,891 
Net income— 143,927 — 143,927 
Other comprehensive loss— — 588 588 
Other— (12)— (12)
Balance at June 30, 2021$— $7,763,886 $4,508 $7,768,394 
Balance at December 31, 2021$— $8,172,294 $8,278 $8,180,572 
Net income— 150,860 — 150,860 
Other comprehensive loss— — (613)(613)
Common equity distributions — (125,000)— (125,000)
Other— (13)— (13)
Balance at March 31, 2022— 8,198,141 7,665 8,205,806 
Net income258 316,401 — 316,659 
Other comprehensive income— — (491)(491)
Capital contribution from parent— 1,000,000 — 1,000,000 
Beneficial interest in storm trust31,636 — — 31,636 
Other— (13)— (13)
Balance at June 30, 2022$31,894 $9,514,529 $7,174 $9,553,597 
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

Net income decreased $2.5 million primarily due to regulatory credits recorded in the second quarter 2021 to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding, higher depreciation and amortization expenses, and higher interest expense, partially offset by higher volume/weather, higher retail electric price, and higher other income.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Net income increased $1.9 million primarily due to higher retail electric price, higher volume/weather, and higher other income, partially offset by regulatory credits recorded in the second quarter 2021 to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding, higher depreciation and amortization expenses, and higher interest expense.

Operating Revenues

Second Quarter 2022 Compared to Second Quarter 2021

Following is an analysis of the change in operating revenues comparing the second quarter 2022 to the second quarter 2021:
Amount
(In Millions)
2021 operating revenues$349.0 
Fuel, rider, and other revenues that do not significantly affect net income33.9 
Volume/weather12.1 
Retail electric price10.5 
2022 operating revenues$405.5 

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

The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales.

The retail electric price variance is primarily due to increases in formula rate plan rates effective July 2021 and April 2022. See Note 2 to the financial statements herein for further discussion of the formula rate plan filings.


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Total electric energy sales for Entergy Mississippi for the three months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential1,419 1,281 11 
Commercial1,167 1,108 5 
Industrial593 585 1 
Governmental106 101 5 
  Total retail 3,285 3,075 7 
Sales for resale:
  Non-associated companies677 1,643 (59)
Total3,962 4,718 (16)

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$685.7 
Fuel, rider, and other revenues that do not significantly affect net income31.6 
Retail electric price26.9 
Volume/weather10.3 
2022 operating revenues$754.5 

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 April 2021, July 2021, and April 2022. See Note 2 to the financial statements herein for further discussion of the formula rate plan filings.

The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales. The increased usage from commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.


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Total electric energy sales for Entergy Mississippi for the six months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential2,714 2,630 3 
Commercial2,188 2,112 4 
Industrial1,154 1,112 4 
Governmental201 197 2 
  Total retail 6,257 6,051 3 
Sales for resale:
  Non-associated companies1,212 3,096 (61)
Total7,469 9,147 (18)

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

Other Income Statement Variances

Second Quarter 2022 Compared to Second Quarter 2021

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

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 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 in the Form 10-K for discussion of the 2021 formula rate plan filing.

Other income increased primarily due to higher interest income from carrying costs related to the deferred fuel balance.

Interest expense increased primarily due to the issuance of $200 million of 2.55% Series mortgage bonds in November 2021.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

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

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 in the Form 10-K for discussion of the 2021 formula rate plan filing.

Other income increased primarily due to higher interest income from carrying costs related to the deferred fuel balance.


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Interest expense increased primarily due to the issuance of $200 million of 3.50% Series mortgage bonds in March 2021 and the issuance of $200 million of 2.55% Series mortgage bonds in November 2021.

Income Taxes

The effective income tax rates were 22% for the second quarter 2022 and 21.3% for the six months ended June 30, 2022. The differences in the effective income tax rates for the second quarter 2022 and the six months ended June 30, 2022 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.

The effective income tax rate was 21.9% for the second quarter 2021 and 22% for the six months ended June 30, 2021. The differences in the effective income tax rates for the second quarter 2021 and the six months ended June 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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Cash and cash equivalents at beginning of period$47,627 $18 
Net cash provided by (used in):
Operating activities20,404 121,636 
Investing activities(295,818)(323,460)
Financing activities253,895 201,817 
Net decrease in cash and cash equivalents(21,519)(7)
Cash and cash equivalents at end of period$26,108 $11 

Operating Activities

Net cash flow provided by operating activities decreased by $101.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to the timing of payments to vendors, increased fuel costs, and income tax refunds of $8 million received in 2021 in accordance with an intercompany income tax allocation agreement. The decrease was partially offset by higher collections from customers and a decrease of $17.5 million in storm spending in 2022, primarily due to Winter Storm Uri restoration efforts in 2021. See Note 2 to the financial statements herein for a discussion of fuel and purchased power cost recovery.

Investing Activities

Net cash flow used in investing activities decreased $27.6 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to a decrease of $91.8 million in distribution construction expenditures due to a higher scope of work performed in 2021 as compared to 2022, lower capital expenditures for storm restoration in 2022, and lower spending in 2022 on advanced metering infrastructure, as well as money pool activity. The decrease was partially offset by the initial payment of approximately $105.1 million in

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May 2022 for the purchase of the Sunflower Solar facility by the tax equity partnership. See Note 14 to the financial statements herein for further discussion of the Sunflower Solar facility purchase.

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 $37.5 million for the six months ended June 30, 2022. 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 $52.1 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•proceeds received in June 2022 from a $150 million unsecured term loan due December 2023;
•borrowings of $100 million in 2022 on Entergy Mississippi’s credit facility; and
•a capital contribution of $9.6 million received in May 2022 from the noncontrolling tax equity investor in MS Sunflower Partnership, LLC and used by the partnership for the initial payment in the acquisition of the Sunflower Solar facility. See Note 14 to the financial statements herein for discussion of the Sunflower Solar facility purchase.

The increase was partially offset by the issuance of $200 million of 3.50% Series mortgage bonds in March 2021.

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

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Mississippi is primarily due to the issuance of long-term debt in 2022.
June 30,
 2022		December 31,
2021
Debt to capital55.9 %54.3 %
Effect of subtracting cash(0.3 %)(0.5 %)
Net debt to net capital55.6 %53.8 %

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 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 Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

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


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Following are the current annual amounts of Entergy Mississippi’s planned construction and other capital investments.
 202220232024
 (In Millions)
Planned construction and capital investment:  
Generation$225 $85 $50 
Transmission85 115 120 
Distribution230 250 225 
Utility Support100 50 30 
Total$640 $500 $425 

The updated capital plan for 2022-2024 reflects accelerated resilience spending. The capital plan includes generation projects to modernize, decarbonize, and diversify Entergy Mississippi’s portfolio, such as Sunflower Solar; distribution and Utility support spending to improve reliability, resilience, and customer experience; transmission spending to drive reliability and resilience while supporting renewables expansion; and other investments.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:
June 30,
 2022		December 31,
2021		June 30,
 2021		December 31,
2020
(In Thousands)
$2,984$40,456($16,998)($16,516)

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 $95 million scheduled to expire in April 2023. As of June 30, 2022, there were no cash borrowings outstanding under these credit facilities. Also, Entergy Mississippi has a credit facility in the amount of $150 million scheduled to expire in July 2024. As of June 30, 2022, there was $100 million in cash borrowings outstanding under the credit facility. 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 June 30, 2022, $4.3 million in MISO letters of credit and $7 million in 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 had $33.2 million in its storm reserve escrow account at June 30, 2022.

Sunflower Solar

As discussed in the Form 10-K, 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. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. In July 2022, pursuant to the MPSC’s April 2020 order, Entergy Mississippi submitted a compliance filing to the MPSC with updated calculations of the impact of the Sunflower Solar facility on rate base and revenue requirement for the Sunflower Solar facility and benefits of the tax equity partnership. A final payment will be made upon substantial completion of the facility and is currently expected in third quarter 2022. See Note 14 to the financial statements herein for discussion of Entergy Mississippi’s purchase of the Sunflower Solar facility.


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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.

Fuel and purchased power cost recovery

See “Complaints Against System Energy - System Energy Settlement with the MPSC” in Note 2 to the financial statements herein for discussion of the settlement agreement filed with the FERC in June 2022. The settlement, which is contingent upon FERC approval, provides for a refund of $235 million from System Energy to Entergy Mississippi. In July 2022 the MPSC directed the disbursement of settlement proceeds, ordering Entergy Mississippi to provide a one-time $80 bill credit to each of its approximately 460,000 retail customers to be effective during the September 2022 billing cycle, and to apply the remaining proceeds to Entergy Mississippi’s under-recovered deferred fuel balance.

Retail Rates

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% 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 $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022.

In June 2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2022 test year filing that resulted in a total rate increase of $48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2021 look-back filing reflected an earned return on rate base of 5.99% in calendar year 2021, which is below the look-back bandwidth, resulting in a $34.3 million increase in the formula rate plan revenues on an interim basis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective in August 2022.

In July 2022 the MPSC directed Entergy Mississippi to flow $14.1 million of the power management rider over-recovery balance to customers beginning in August 2022 through December 2022 to mitigate the bill impact of the increase in formula rate plan revenues.

Net Metering Rulemaking

Pursuant to a mandatory reopener provision in its net metering rule, the MPSC opened a docket to review the efficacy and fairness of its existing net metering rule. In July 2022 the MPSC issued an order adopting revisions to its net metering rule. Among other things, the amended rule requires utilities to calculate avoided cost using daytime energy production, grandfathers a 2.5 cents per kWh distributed generation benefits adder for 25 years, and expands eligibility for the 2 cents per kWh low-income benefits adder to households up to 250% of the federal poverty level and grandfathers that adder for 25 years. The amended rule expands meter aggregation to include

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systems up to 3 MW alternating current and to any additional meters within the same electric utility service territory. The amended rule also increases the 3% net metering participation cap to 4% and requires that utilities seek MPSC approval prior to refusing additional net generation requests. The MPSC also directs utilities to make rate filings implementing rebates for distributed generation facilities. Because of the size and number of customers eligible under this new rule, there is a risk of loss of load and the shifting of costs to customers. Entergy Mississippi continues to review the rule and consider its effects.

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 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of June 30, 2022, Entergy Mississippi had a regulatory asset of $13.1 million for costs associated with the COVID-19 pandemic. Entergy Mississippi received approval to recover this regulatory asset through its formula rate plan rider over a three-year period beginning August 2022.

Federal Regulation

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

Nuclear Matters

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

Environmental Risks

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

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

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 Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$405,459 $349,040 $754,488 $685,659 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale43,671 65,613 110,948 125,810 
Purchased power89,346 63,892 150,558 132,483 
Other operation and maintenance74,898 73,899 140,709 141,730 
Taxes other than income taxes32,484 27,076 65,214 52,975 
Depreciation and amortization60,618 56,158 120,702 111,194 
Other regulatory charges (credits) - net23,853 (21,630)27,760 (13,501)
TOTAL324,870 265,008 615,891 550,691 
OPERATING INCOME80,589 84,032 138,597 134,968 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction1,495 2,029 2,573 3,697 
Interest and investment income34 7 98 49 
Miscellaneous - net990 (2,205)(164)(4,518)
TOTAL2,519 (169)2,507 (772)
INTEREST EXPENSE
Interest expense21,003 18,922 41,437 36,535 
Allowance for borrowed funds used during construction(658)(852)(1,123)(1,529)
TOTAL20,345 18,070 40,314 35,006 
INCOME BEFORE INCOME TAXES62,763 65,793 100,790 99,190 
Income taxes13,808 14,377 21,481 21,802 
NET INCOME 48,955 51,416 79,309 77,388 
Net income attributable to noncontrolling interest— — — — 
EARNINGS APPLICABLE TO MEMBER'S EQUITY$48,955 $51,416 $79,309 $77,388 
See Notes to Financial Statements.



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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income$79,309 $77,388 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization120,702 111,194 
Deferred income taxes, investment tax credits, and non-current taxes accrued17,628 33,499 
Changes in assets and liabilities:
Receivables(38,137)(9,164)
Fuel inventory(5,352)954 
Accounts payable23,252 38,287 
Taxes accrued(36,021)(49,438)
Interest accrued498 (4,623)
Deferred fuel costs(124,752)(46,714)
Other working capital accounts(36,211)(27,684)
Provisions for estimated losses(194)(7,860)
Other regulatory assets3,332 (13,050)
Other regulatory liabilities15,441 13,520 
Pension and other postretirement liabilities(8,004)(10,086)
Other assets and liabilities8,913 15,413 
Net cash flow provided by operating activities20,404 121,636 
INVESTING ACTIVITIES
Construction expenditures(230,683)(327,163)
Allowance for equity funds used during construction2,573 3,697 
Changes in money pool receivable - net37,472 — 
Payment for the purchase of plant or assets(105,149)— 
Other(31)6 
Net cash flow used in investing activities(295,818)(323,460)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt249,746 200,543 
Capital contribution from noncontrolling interest9,595 — 
Changes in money pool payable - net— 482 
Other(5,446)792 
Net cash flow provided by financing activities253,895 201,817 
Net decrease in cash and cash equivalents(21,519)(7)
Cash and cash equivalents at beginning of period47,627 18 
Cash and cash equivalents at end of period$26,108 $11 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized$39,620 $39,925 
Income taxes$— ($8,045)
See Notes to Financial Statements.

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CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
 20222021
 (In Thousands)
CURRENT ASSETS  
Cash and cash equivalents:  
Cash$36 $29 
Temporary cash investments26,072 47,598 
Total cash and cash equivalents26,108 47,627 
Accounts receivable:  
Customer93,171 84,048 
Allowance for doubtful accounts(2,222)(7,209)
Associated companies13,526 42,994 
Other12,250 14,609 
Accrued unbilled revenues74,416 56,034 
Total accounts receivable191,141 190,476 
Deferred fuel costs246,630 121,878 
Fuel inventory - at average cost15,663 10,311 
Materials and supplies - at average cost79,390 69,639 
Prepayments and other28,494 6,394 
TOTAL587,426 446,325 
OTHER PROPERTY AND INVESTMENTS  
Non-utility property - at cost (less accumulated depreciation)4,519 4,527 
Escrow accounts41,067 48,886 
TOTAL45,586 53,413 
UTILITY PLANT  
Electric6,724,036 6,613,109 
Construction work in progress266,686 95,452 
TOTAL UTILITY PLANT6,990,722 6,708,561 
Less - accumulated depreciation and amortization2,204,547 2,127,590 
UTILITY PLANT - NET4,786,175 4,580,971 
DEFERRED DEBITS AND OTHER ASSETS  
Regulatory assets:  
Other regulatory assets459,100 462,432 
Other18,613 14,248 
TOTAL477,713 476,680 
TOTAL ASSETS$5,896,900 $5,557,389 
See Notes to Financial Statements.  

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CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
 20222021
 (In Thousands)
CURRENT LIABILITIES  
Accounts payable:  
Associated companies$45,337 $42,929 
Other133,452 113,000 
Customer deposits88,087 86,167 
Taxes accrued70,252 106,273 
Interest accrued17,781 17,283 
Other22,629 36,731 
TOTAL377,538 402,383 
NON-CURRENT LIABILITIES  
Accumulated deferred income taxes and taxes accrued741,539 720,097 
Accumulated deferred investment tax credits10,801 10,913 
Regulatory liability for income taxes - net206,932 212,445 
Other regulatory liabilities70,267 49,313 
Asset retirement cost liabilities10,603 10,315 
Accumulated provisions37,834 38,028 
Pension and other postretirement liabilities50,945 59,065 
Long-term debt2,430,499 2,179,989 
Other31,469 35,273 
TOTAL3,590,889 3,315,438 
Commitments and Contingencies  
EQUITY  
Member's equity1,918,878 1,839,568 
Noncontrolling interest9,595 — 
TOTAL1,928,473 1,839,568 
TOTAL LIABILITIES AND EQUITY$5,896,900 $5,557,389 
See Notes to Financial Statements.  

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
  
 Noncontrolling InterestMember's EquityTotal
 (In Thousands)
Balance at December 31, 2020$— $1,672,734 $1,672,734 
Net income— 25,972 25,972 
Balance at March 31, 2021— 1,698,706 1,698,706 
Net income— 51,416 51,416 
Balance at June 30, 2021$— $1,750,122 $1,750,122 
Balance at December 31, 2021$— $1,839,568 $1,839,568 
Net income— 30,355 30,355 
Balance at March 31, 2022— 1,869,923 1,869,923 
Net income— 48,955 48,955 
Capital contribution from noncontrolling interest9,595 — 9,595 
Balance at June 30, 2022$9,595 $1,918,878 $1,928,473 
See Notes to Financial Statements.

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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

Net income increased $14.9 million primarily due to higher volume/weather and higher retail electric price, partially offset by higher other operation and maintenance expenses, higher taxes other than income taxes, and higher interest expense.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Net income increased $28.3 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher interest expense and higher taxes other than income taxes.

Operating Revenues

Second Quarter 2022 Compared to Second Quarter 2021

Following is an analysis of the change in operating revenues comparing second quarter 2022 to second quarter 2021:
Amount
(In Millions)
2021 operating revenues$178.7 
Fuel, rider, and other revenues that do not significantly affect net income52.7 
Volume/weather12.9 
Retail electric price9.9 
2022 operating revenues$254.2 

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 volume/weather variance is primarily due to an increase in weather-adjusted residential usage and the effect of more favorable weather on residential sales.

The retail electric price variance is primarily due to a rate increase effective November 2021 in accordance with the terms of the 2021 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.


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Total electric energy sales for Entergy New Orleans for the three months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential669 563 19 
Commercial543 507 7 
Industrial116 111 5 
Governmental206 198 4 
  Total retail 1,534 1,379 11 
Sales for resale:
  Non-associated companies605 530 14 
Total2,139 1,909 12 

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$348.1 
Fuel, rider, and other revenues that do not significantly affect net income68.5 
Retail electric price20.2 
Volume/weather15.7 
2022 operating revenues$452.5 

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 a rate increase effective November 2021 in accordance with the terms of the 2021 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to an increase in weather-adjusted residential usage, an increase in commercial usage, and the effect of more favorable weather on residential sales. The increase in commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in 2021.


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Total electric energy sales for Entergy New Orleans for the six months ended June 30, 2022 and 2021 are as follows:
20222021% Change
(GWh)
Residential1,207 1,101 10 
Commercial1,008 953 6 
Industrial210 205 2 
Governmental383 370 4 
  Total retail 2,808 2,629 7 
Sales for resale:
  Non-associated companies1,321 619 113 
Total4,129 3,248 27 

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

Other Income Statement Variances

Second Quarter 2022 Compared to Second Quarter 2021

Other operation and maintenance expenses increased primarily due to an increase of $1.3 million in loss provisions and an increase of $1.2 million in power delivery expenses primarily due to higher reliability costs, higher safety and training costs, and higher vegetation maintenance costs, partially offset by a decrease 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 resulting from higher assessments and increases in local franchise taxes.

Interest expense increased primarily due to the issuance of $90 million of 4.19% Series mortgage bonds and the issuance of $70 million of 4.51% Series mortgage bonds, each in November 2021.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Other operation and maintenance expenses decreased primarily due to a decrease of $2 million in energy efficiency expenses resulting from the timing of recovery from customers.

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

Interest expense increased primarily due to the issuance of $90 million of 4.19% Series mortgage bonds and the issuance of $70 million of 4.51% Series mortgage bonds, each in November 2021.

Income Taxes

The effective income tax rate was 27.2% for second quarter 2022. The difference in the effective income tax rate for second quarter 2022 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.


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The effective income tax rate was 23.4% for the six months ended June 30, 2022. The difference in the effective income tax rate for the six months ended June 30, 2022 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 of and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 28% for second quarter 2021 and 29.8% for the six months ended June 30, 2021. The differences in the effective income tax rates for second quarter 2021 and the six months ended June 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.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Cash and cash equivalents at beginning of period$42,862 $26 
Net cash provided by (used in):
Operating activities55,623 27,188 
Investing activities(81,900)(48,660)
Financing activities9,766 21,472 
Net decrease in cash and cash equivalents(16,511)— 
Cash and cash equivalents at end of period$26,351 $26 

Operating Activities

Net cash flow provided by operating activities increased $28.4 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to higher collections from customers.

The increase was partially offset by:

•the timing of payments to vendors;
•increased fuel costs. See Note 2 to the financial statements in the Form 10-K for a discussion of fuel and purchased power cost recovery; and
•an increase of $12.7 million in storm spending in 2022, primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K and Note 2 to the financial statements herein for a discussion of hurricane restoration efforts.

Investing Activities

Net cash flow used in investing activities increased $33.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•$44.2 million in receipts from storm reserve escrow accounts in 2021; and

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•an increase of $33.5 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration in 2022. The increase in storm restoration spending is primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K and Note 2 to the financial statements herein for a discussion of hurricane restoration efforts.

The increase was partially offset by money pool activity and a decrease of $9.4 million in non-nuclear generation construction expenditures primarily due to a lower scope of work performed during plant outages in 2022.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased $33.5 million for the six months ended June 30, 2022. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities decreased $11.7 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to money pool activity, partially offset by a $15 million advance received in 2022 in anticipation of Entergy New Orleans’s construction of a New Orleans Sewerage and Water Board substation.

Increases in Entergy New Orleans’s payable to the money pool are a source of cash flow, and Entergy New Orleans’s payable to the money pool increased $27.7 million for the six months ended June 30, 2021.

Capital Structure

Entergy New Orleans’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due an increase in equity resulting from retained earnings in 2022.
June 30,
2022		December 31,
2021
Debt to capital53.9 %55.4 %
Effect of excluding securitization bonds (0.8 %)(1.0 %)
Debt to capital, excluding securitization bonds (a)53.1 %54.4 %
Effect of subtracting cash(0.8 %)(1.4 %)
Net debt to net capital, excluding securitization bonds (a)52.3 %53.0 %

(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 net debt indicates Entergy New Orleans’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 New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.  

The current annual amounts of Entergy New Orleans’s planned construction and other capital investments are as follows:

 202220232024
 (In Millions)
Planned construction and capital investment:  
Generation$5 $5 $5 
Transmission20 20 20 
Distribution110 115 190 
Utility Support25 15 10 
Total$160 $155 $225 

The updated capital plan for 2022-2024 reflects accelerated resilience spending. The capital plan includes generation projects to modernize, decarbonize, and diversify Entergy New Orleans’s portfolio; distribution and Utility support spending to improve reliability, resilience, and customer experience; transmission spending to drive reliability and resilience while supporting renewables expansion; and other investments.

Entergy New Orleans’s receivables from or (payables to) the money pool were as follows:
June 30,
2022		December 31,
2021		June 30,
2021		December 31,
2020
(In Thousands)
$2,937$36,410($37,874)($10,190)

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 June 30, 2022, there were no cash borrowings and no letters of credit outstanding under the credit facility. In addition, Entergy New Orleans is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2022, 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.

In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. A City Council decision is expected in third quarter 2022.

Hurricane Zeta

As discussed in the Form 10-K, 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

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Zeta of approximately $36 million, which included $7 million in estimated 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. In May 2022 the City Council advisors issued a report recommending that the City Council find that Entergy New Orleans acted prudently in restoring service following Hurricane Zeta and approximately $33 million in storm restoration costs were prudently incurred and recoverable. Additionally, the advisors concluded that approximately $7 million of the $44 million withdrawn from its funded storm reserve was in excess of Entergy New Orleans’s costs and should be considered in Entergy New Orleans’s application for certification of costs related to Hurricane Ida, as discussed below.

Hurricane Ida

As discussed in the Form 10-K, 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 damage to distribution and transmission infrastructure, including the loss of connectivity to the eastern interconnection. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. In June 2022, Entergy New Orleans filed an application with the City Council requesting approval and certification that storm restoration costs associated with Hurricane Ida of approximately $170 million were reasonable, necessary, and prudently incurred to enable Entergy New Orleans to restore electric service to its customers and to repair Entergy New Orleans’s electric utility infrastructure. Carrying costs through December 2022 related to Hurricane Ida restoration costs were $9 million. Additionally, Entergy New Orleans is requesting approval that the $39 million withdrawal from its funded storm reserve in September 2021 and $7 million in excess storm reserve escrow withdrawals related to Hurricane Zeta and prior miscellaneous storms are properly applied to Hurricane Ida storm restoration costs, the application of which reduces the amount to be recovered from Entergy New Orleans customers by $46 million. The City Council has not yet set a procedural schedule regarding the requested relief, though Entergy New Orleans requested resolution by the end of first quarter 2023. Entergy New Orleans intends to file with the City Council an application proposing a financing method for recovery of costs deemed eligible for recovery.

State and Local Rate Regulation

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

Retail Rates

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report, subsequently updated in a July 2022 filing, produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $42.1 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $34.1 million and an increase in authorized gas revenues of $3.3 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. In July 2022 the City Council’s advisors issued a report seeking a reduction to Entergy New Orleans’s proposed increase of approximately $17.1 million in total for electric and gas revenues. The parties have a 25-day period to attempt to reach an agreement on the final amount to increase revenues, with implementation of resulting rates effective with the first billing cycle of September 2022 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council will set a procedural schedule that will extend the process for City Council approval of disputed rate adjustments.


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COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of June 30, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic. As part of its 2022 formula rate plan filing, Entergy New Orleans requested recovery of this regulatory asset over a five-year period beginning September 2022.

Reliability Investigation

As discussed in the Form 10-K, in April 2018 the City Council adopted a resolution directing Entergy New Orleans to demonstrate that it has been prudent in the management and maintenance of the reliability of its distribution system. The City Council also approved a resolution that opened a prudence investigation into whether Entergy New Orleans was imprudent for not acting sooner to address outages in New Orleans and whether fines should be imposed. In January 2019, Entergy New Orleans filed testimony in response to the prudence investigation and asserting that it had been prudent in managing system reliability. In April 2019 the City Council advisors filed comments and testimony asserting that Entergy New Orleans did not act prudently in maintaining and improving its distribution system reliability in recent years and recommending that a financial penalty in the range of $1.5 million to $2 million should be assessed.  Entergy New Orleans disagreed with the recommendation and submitted rebuttal testimony and rebuttal comments in June 2019. In November 2019 the City Council passed a resolution that penalized Entergy New Orleans $1 million for alleged imprudence in the maintenance of its distribution system. In December 2019, Entergy New Orleans filed suit in Louisiana state court seeking judicial review of the City Council’s resolution. In June 2022 the Orleans Civil District Court issued a written judgment that the penalty be set aside, reversed, and vacated. The City Council filed a motion to remand to the City Council for further consideration, and Entergy New Orleans opposed the motion. The parties await written reasons for judgment and a ruling from the Civil District Court on the motion to remand.

System Resiliency and Storm Hardening

As discussed in the Form 10-K, in October 2021 the City Council passed a resolution and order establishing a docket and procedural schedule with respect to system resiliency and storm hardening. The docket will identify a plan for storm hardening and resiliency projects with other stakeholders. In July 2022, Entergy New Orleans filed with the City Council a response identifying a plan for storm hardening and resiliency projects, including alternative technologies, to be implemented over 10 years at an approximate cost of $1.5 billion.

Federal Regulation

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

Nuclear Matters

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

Environmental Risks

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


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Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

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 Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$224,084 $159,761 $378,730 $298,909 
Natural gas30,165 18,979 73,791 49,166 
TOTAL254,249 178,740 452,521 348,075 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale54,815 34,510 98,212 53,522 
Purchased power83,088 57,177 139,558 125,847 
Other operation and maintenance43,715 40,977 77,367 79,155 
Taxes other than income taxes14,444 12,294 28,433 24,850 
Depreciation and amortization17,951 18,153 37,766 36,314 
Other regulatory charges (credits) - net5,354 2,575 9,539 5,705 
TOTAL219,367 165,686 390,875 325,393 
OPERATING INCOME34,882 13,054 61,646 22,682 
OTHER INCOME
Allowance for equity funds used during construction(449)376 (80)634 
Interest and investment income68 5 92 14 
Miscellaneous - net1,221 (204)950 (506)
TOTAL840 177 962 142 
INTEREST EXPENSE
Interest expense8,698 6,962 17,392 13,991 
Allowance for borrowed funds used during construction159 (167)(40)(283)
TOTAL8,857 6,795 17,352 13,708 
INCOME BEFORE INCOME TAXES26,865 6,436 45,256 9,116 
Income taxes7,319 1,805 10,584 2,714 
NET INCOME$19,546 $4,631 $34,672 $6,402 
See Notes to Financial Statements.


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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income$34,672 $6,402 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization37,766 36,314 
Deferred income taxes, investment tax credits, and non-current taxes accrued16,265 4,907 
Changes in assets and liabilities:
Receivables9,240 (15,306)
Fuel inventory(844)725 
Accounts payable3,909 (7,309)
Taxes accrued(2,524)948 
Interest accrued(361)(1,315)
Deferred fuel costs(31,599)4,423 
Other working capital accounts(9,725)(11,944)
Provisions for estimated losses6,319 (40,152)
Other regulatory assets24,541 35,038 
Other regulatory liabilities(15,456)4,823 
Pension and other postretirement liabilities(4,741)(7,352)
Other assets and liabilities(11,839)16,986 
Net cash flow provided by operating activities55,623 27,188 
INVESTING ACTIVITIES
Construction expenditures(115,552)(94,173)
Allowance for equity funds used during construction(80)634 
Changes in money pool receivable - net33,473 — 
Receipts from storm reserve escrow account— 44,200 
Payments to storm reserve escrow account— (7)
Changes in securitization account259 686 
Net cash flow used in investing activities(81,900)(48,660)
FINANCING ACTIVITIES
Retirement of long-term debt(5,916)(5,749)
Changes in money pool payable - net— 27,684 
Other15,682 (463)
Net cash flow provided by financing activities9,766 21,472 
Net decrease in cash and cash equivalents(16,511)— 
Cash and cash equivalents at beginning of period42,862 26 
Cash and cash equivalents at end of period$26,351 $26 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$17,055 $14,684 
Income taxes$— $324 
See Notes to Financial Statements.

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CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$686 $26 
Temporary cash investments25,665 42,836 
Total cash and cash equivalents26,351 42,862 
Securitization recovery trust account1,740 1,999 
Accounts receivable: 
Customer77,869 69,902 
Allowance for doubtful accounts(6,913)(13,282)
Associated companies6,489 74,146 
Other8,912 13,668 
Accrued unbilled revenues40,914 25,550 
Total accounts receivable127,271 169,984 
Deferred fuel costs23,992 — 
Fuel inventory - at average cost3,789 2,945 
Materials and supplies - at average cost21,623 19,216 
Prepayments and other15,018 5,428 
TOTAL219,784 242,434 
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)1,044 1,016 
TOTAL1,044 1,016 
UTILITY PLANT
Electric1,976,201 1,976,202 
Natural gas380,217 373,983 
Construction work in progress32,408 22,199 
TOTAL UTILITY PLANT2,388,826 2,372,384 
Less - accumulated depreciation and amortization798,549 774,309 
UTILITY PLANT - NET1,590,277 1,598,075 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs4,080 4,080 
Other regulatory assets (includes securitization property of $19,906 as of June 30, 2022 and $25,761 as of December 31, 2021)
224,076 248,617 
Other62,756 56,101 
TOTAL290,912 308,798 
TOTAL ASSETS$2,102,017 $2,150,323 
See Notes to Financial Statements.

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CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$70,000 $— 
Payable due to associated company1,326 1,326 
Accounts payable:
Associated companies51,740 45,057 
Other66,467 146,921 
Customer deposits30,425 28,539 
Taxes accrued1,861 4,385 
Interest accrued7,630 7,991 
Deferred fuel costs— 7,607 
Current portion of unprotected excess accumulated deferred income taxes— 1,906 
Other6,706 6,204 
TOTAL236,155 249,936 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued382,567 365,384 
Accumulated deferred investment tax credits16,287 16,306 
Regulatory liability for income taxes - net38,809 40,589 
Asset retirement cost liabilities— 4,032 
Accumulated provisions12,648 6,329 
Long-term debt (includes securitization bonds of $23,866 as of June 30, 2022 and $29,661 as of December 31, 2021)
701,904 777,254 
Long-term payable due to associated company9,585 9,585 
Other30,675 42,193 
TOTAL1,192,475 1,261,672 
Commitments and Contingencies
EQUITY
Member's equity673,387 638,715 
TOTAL673,387 638,715 
TOTAL LIABILITIES AND EQUITY$2,102,017 $2,150,323 
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
  
 Member's Equity
 (In Thousands)
Balance at December 31, 2020$606,917 
Net income1,771 
Balance at March 31, 2021608,688 
Net income4,631 
Balance at June 30, 2021$613,319 
Balance at December 31, 2021$638,715 
Net income15,126 
Balance at March 31, 2022653,841 
Net income19,546 
Balance at June 30, 2022$673,387 
See Notes to Financial Statements. 


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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

Net income increased $52.7 million primarily due to higher volume/weather, the recognition of the equity component of carrying costs as part of the securitization of the Hurricane Laura, Hurricane Delta, and Winter Storm Uri system restoration costs in April 2022, and higher retail electric price. The increase was partially offset by higher depreciation and amortization expenses and higher taxes other than income taxes.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Net income increased $53 million primarily due to higher volume/weather, higher retail electric price, and the recognition of the equity component of carrying costs as part of the securitization of the Hurricane Laura, Hurricane Delta, and Winter Storm Uri system restoration costs in April 2022. The increase was partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Operating Revenues

Second Quarter 2022 Compared to Second Quarter 2021

Following is an analysis of the change in operating revenues comparing the second quarter 2022 to the second quarter 2021:
Amount
(In Millions)
2021 operating revenues$430.4 
Fuel, rider, and other revenues that do not significantly affect net income64.1 
Volume/weather40.4 
System restoration carrying costs21.7 
Retail electric price8.0 
2022 operating revenues$564.6 

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 volume/weather variance is primarily due to an increase in weather-adjusted residential usage, an increase in industrial and commercial usage, and the effect of more favorable weather on residential sales. The increase in weather-adjusted residential usage was primarily due to an increase in customers. The increase in industrial usage was primarily due to an increase in demand from cogeneration customers and an increase in demand from expansion projects and existing customers, both primarily in the transportation industry. The increase

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in commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in second quarter 2021.

System restoration carrying costs represent the equity component of system restoration carrying costs, recorded in second quarter 2022, recognized as part of the securitization of the Hurricane Laura, Hurricane Delta, and Winter Storm Uri system restoration costs in April 2022. See Note 2 to the financial statements herein for a discussion of the securitization.

The retail electric price variance is primarily due to an increase in the transmission cost recovery factor rider effective March 2022 and an increase in the distribution cost recovery factor rider effective January 2022. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the transmission and distribution cost recovery factor rider filings.

Total electric energy sales for Entergy Texas for the three months ended June 30, 2022 and 2021 are as follows:
2022
2021
% Change
(GWh)
Residential1,760 1,486 18 
Commercial1,231 1,101 12 
Industrial2,489 2,182 14 
Governmental67 59 14 
  Total retail 5,547 4,828 15 
Sales for resale:
  Associated companies89 363 (75)
  Non-associated companies161 291 (45)
Total5,797 5,482 6 

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2022 to the six months ended June 30, 2021:
Amount
(In Millions)
2021 operating revenues$910.7 
Fuel, rider, and other revenues that do not significantly affect net income35.7 
Volume/weather40.5 
Retail electric price28.5 
System restoration carrying costs21.7 
2022 operating revenues$1,037.1 

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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 in industrial usage, an increase in weather-adjusted residential usage, and the effect of more favorable weather on residential sales. The increase in industrial usage was primarily due to an increase in demand from cogeneration and small industrial customers, an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from existing customers, primarily in the transportation, chemicals, and petroleum refining industries. The increase in weather-adjusted residential usage was primarily due to an increase in customers. The increased usage from these industrial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

The retail electric price variance is primarily due to:

•increases in the transmission cost recovery factor rider effective March 2021 and March 2022;
•an increase in the distribution cost recovery factor rider effective January 2022; and
•an increase in the generation cost recovery rider effective in late January 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.

System restoration carrying costs represent the equity component of system restoration carrying costs, recorded in second quarter 2022, recognized as part of the securitization of the Hurricane Laura, Hurricane Delta, and Winter Storm Uri system restoration costs in April 2022. See Note 2 to the financial statements herein for a discussion of the securitization.

Total electric energy sales for Entergy Texas for the six months ended June 30, 2022 and 2021 are as follows:
2022
2021
% Change
(GWh)
Residential3,220 2,880 12 
Commercial2,290 2,105 9 
Industrial4,753 4,145 15 
Governmental131 121 8 
  Total retail 10,394 9,251 12 
Sales for resale:
  Associated companies279 659 (58)
  Non-associated companies305 633 (52)
Total10,978 10,543 4 

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


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Other Income Statement Variances

Second Quarter 2022 Compared to Second Quarter 2021

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

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

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

Other operation and maintenance expenses increased primarily due to:

•an increase of $5 million in non-nuclear generation expenses primarily due to higher expenses associated with the Hardin County Peaking Facility, which was purchased in June 2021, and a higher scope of work performed in 2022 as compared to the same period in 2021;
•an increase of $4 million in power delivery expenses primarily due to higher reliability costs partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;
•an increase of $1.8 million in customer service center support costs primarily due to higher contract costs; and
•several individually insignificant items.

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

Income Taxes

The effective income tax rates were 14.5% for the second quarter 2022 and 12.8% for the six months ended June 30, 2022. The differences in the effective income tax rates for the second quarter 2022 and the six months ended June 30, 2022 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.

The effective income tax rates were 8.4% for the second quarter 2021 and 8.8% for the six months ended June 30, 2021. The differences in the effective income tax rates for the second quarter 2021 and the six months ended June 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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Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Cash and cash equivalents at beginning of period$28 $248,596 
Net cash provided by (used in):
Operating activities171,727 119,535 
Investing activities(326,373)(350,305)
Financing activities177,193 (17,801)
Net increase (decrease) in cash and cash equivalents22,547 (248,571)
Cash and cash equivalents at end of period$22,575 $25 

Operating Activities

Net cash flow provided by operating activities increased $52.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•the timing of payments to vendors;
•higher collections from customers; and
•a decrease of approximately $22.5 million in storm spending in 2022, primarily due to Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration efforts in 2021.

The increase was partially offset by the timing of recovery of fuel and purchased power costs. See Note 2 to the financial statements herein for a discussion of fuel and purchased power cost recovery.

Investing Activities

Net cash flow used in investing activities decreased $23.9 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•a decrease of $58.6 million in distribution construction expenditures primarily due to lower capital expenditures for storm restoration in 2022, partially offset by higher capital expenditures as a result of increased development in Entergy Texas’s service area. The decrease in storm restoration spending is primarily due to Hurricane Laura restoration efforts in 2021;
•the purchase of the Hardin County Peaking Facility in June 2021 for approximately $36.7 million;
•a decrease of $23.5 million in non-nuclear generation construction expenditures primarily due to a lower scope of work on projects performed in 2022 as compared to 2021; and
•a decrease of $22.5 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 2022 as compared to 2021 and lower capital expenditures for storm restoration in 2022.

The decrease was partially offset by:

•the sale of a 7.56% partial interest in the Montgomery County Power Station in June 2021 for approximately $67.9 million; and

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•cash collateral of $30 million posted in 2022 to support Entergy Texas’s obligations to MISO.

Financing Activities

Entergy Texas’s financing activities provided $177.2 million of cash for the six months ended June 30, 2022 compared to using $17.8 million for the six months ended June 30, 2021 primarily due to the issuance of $290.85 million of senior secured system restoration bonds in April 2022, as discussed below, and the repayment, prior to maturity, of $125 million of 2.55% Series mortgage bonds in May 2021. The activity was partially offset by money pool activity and 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.

Decreases in Entergy Texas’s payable to the money pool are a use of cash flow, and Entergy Texas’s payable to the money pool decreased by $79.6 million for the six months ended June 30, 2022 compared to increasing by $63.4 million for the six months ended June 30, 2021. 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 Texas’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the issuance of long-term debt in 2022, partially offset by an increase in equity resulting from retained earnings.
June 30,
2022		December 31,
2021
Debt to capital49.9 %48.7 %
Effect of excluding the securitization bonds(3.2 %)(0.5 %)
Debt to capital, excluding securitization bonds (a)46.7 %48.2 %
Effect of subtracting cash(0.2 %)— %
Net debt to net capital, excluding securitization bonds (a)46.5 %48.2 %

(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.

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Following are the current annual amounts of Entergy Texas’s planned construction and other capital investments.
 202220232024
 (In Millions)
Planned construction and capital investment:  
Generation$110 $270 $515 
Transmission115 175 185 
Distribution260 390 355 
Utility Support70 70 40 
Total$555 $905 $1,095 

The updated capital plan for 2022-2024 reflects increased capital project costs. The capital plan 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 improve reliability, resilience, and customer experience; transmission spending to drive reliability and resilience while also supporting renewables expansion; and other investments.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:

June 30,
2022		December 31,
2021		June 30,
2021		December 31,
2020
(In Thousands)
$1,643($79,594)($63,437)$4,601

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

Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in June 2027.  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 June 30, 2022, there were no cash borrowings and $1.1 million of letters of credit outstanding under the credit facility.  In addition, Entergy Texas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2022, $79.6 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.

Orange County Advanced Power Station

As discussed in the Form 10-K, 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 initially-estimated expected total cost of $1.2 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. In December 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2022 certain intervenors filed testimony opposing the hydrogen co-firing component of the proposed project and others filed testimony opposing the project outright. Also in March 2022, PUCT staff filed testimony opposing the hydrogen co-firing component of the proposed project, but otherwise taking no specific position on the merits of the project. The PUCT staff also proposed that the PUCT establish a maximum amount that Entergy Texas may recover in rates attributable to the

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project. In April 2022, Entergy Texas filed rebuttal testimony addressing and rebutting these various arguments. Also in April 2022 the ALJs with the State Office of Administrative Hearings approved a continuance of the hearing on the merits from April 2022 to June 2022, providing Entergy Texas an opportunity to accelerate the determination and fixing of pricing for 60 days for the Orange County Advanced Power Station prior to the hearing. In May 2022, Entergy Texas obtained and provided to the parties an updated fixed pricing option of $1.58 billion, available until mid-July 2022. The hearing on the merits was held in June 2022 and post-hearing briefs were submitted in July 2022. The initial fixed pricing window closed in July 2022, and Entergy Texas intends to obtain a new fixed pricing option prior to PUCT approval and issuance of notice to proceed. A final order by the PUCT is expected in the fourth quarter of 2022. Entergy Texas also is pursuing environmental permitting that is required prior to the commencement of construction. Subject to receipt of required regulatory approvals, permits, and other conditions, the facility is expected to be in service by the end of 2026.

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, 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 July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

State and Local Rate Regulation and Fuel-Cost Recovery

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

Retail Rates

2022 Base Rate Case

In July 2022, Entergy Texas filed a base rate case with the PUCT seeking an increase in base rates of approximately $131.4 million. The base rate case was based on a 12-month test year ending December 31, 2021. Key drivers of the requested increase are changes in depreciation rates as the result of a depreciation study and an increase in the return on equity. In addition, Entergy Texas included capital additions placed into service for the period of January 1, 2018 through December 31, 2021, including those additions currently reflected in the distribution and transmission cost recovery factor riders and the generation cost recovery rider, all of which would be reset to zero as a result of this proceeding. In July 2022, the PUCT referred the proceeding to the State Office of

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Administrative Hearings. Also in July 2022, the ALJ with the State Office of Administrative Hearings approved a procedural schedule with a hearing on the merits in December 2022.

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, 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. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 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, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, 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. In January 2022 the PUCT referred the proceeding to the State Office of Administrative Hearings. In February 2022 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 2022. In February 2022 the ALJ granted the motion for interim rates, admitted evidence, and remanded the case to the PUCT for consideration of a final order at a future open meeting. In June 2022 the PUCT issued an order approving the settlement.

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 to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

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 represented no change from the generation cost recovery rider rates 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

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Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility. Concurrently with filing of the unanimous settlement agreement, Entergy Texas submitted an agreed motion to admit evidence and remand the case to the PUCT for review and consideration of the settlement agreement, which motion was granted by the ALJ with the State Office of Administrative Hearings.

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. As of June 30, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic. As part of its 2022 base rate case filing, Entergy Texas requested recovery of its regulatory asset over a three-year period beginning December 2022.

Green Pricing Option Tariffs

In January 2022, Entergy Texas filed an application requesting approval to implement two voluntary renewable option tariffs, Rider Small Volume Renewable Option (Rider SVRO) and Rider Large Volume Renewable Option (Rider LVRO). Both tariffs are voluntary offerings that give customers the ability to match some or all of their monthly electricity usage with renewable energy credits that are purchased by Entergy Texas and retired on the customer’s behalf. Voluntary participation in either Rider SVRO or Rider LVRO and the charges assessed under the respective tariff would be in addition to the charges paid by customers under their otherwise applicable rate schedules and riders. In April 2022, Entergy Texas filed on behalf of the parties an unopposed settlement agreement supporting approval of Entergy Texas’s proposed green pricing option tariffs. As part of the settlement agreement, Entergy Texas agreed to revise the cost allocation between the rate tiers of Rider SVRO and committed to collaborating with and considering the input of customers to develop an asset-backed green tariff program. This matter is awaiting placement on an open meeting agenda for PUCT consideration of the settlement.

Fuel and purchased power recovery

In May 2022, Entergy Texas filed an application with the PUCT to implement an interim fuel surcharge to collect the cumulative under-recovery of approximately $51.7 million, including interest, of fuel and purchased power costs incurred from May 1, 2020 through December 31, 2021. The under-recovery balance is primarily attributable to the impacts of Winter Storm Uri, including historically high natural gas prices, partially offset by settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas proposed that the interim fuel surcharge be assessed over a period of six months beginning with the first billing cycle after the PUCT issues a final order, but no later than the first billing cycle of September 2022. Also in May 2022, the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2022, Entergy Texas filed on behalf of the parties an unopposed settlement resolving all issues in the proceeding. In addition, Entergy Texas filed on behalf of the parties a motion to admit evidence, to approve interim rates as requested in the initial application, and to remand the proceeding to the PUCT to consider the unopposed settlement. In August 2022 the ALJ with the

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State Office of Administrative Hearings issued an order granting Entergy Texas’s motion, approving interim rates effective with the first billing cycle of September 2022, and remanding the case to the PUCT for final approval.

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 the estimates and judgments necessary in Entergy Texas’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. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

New Accounting Pronouncements

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

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$564,591 $430,434 $1,037,073 $910,654 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale60,855 64,031 134,775 176,427 
Purchased power195,016 128,699 356,106 270,061 
Other operation and maintenance72,589 70,815 147,566 133,770 
Taxes other than income taxes23,482 20,671 43,931 42,546 
Depreciation and amortization57,248 53,587 113,309 104,523 
Other regulatory charges (credits) - net22,399 25,253 35,845 41,093 
TOTAL431,589 363,056 831,532 768,420 
OPERATING INCOME133,002 67,378 205,541 142,234 
OTHER INCOME
Allowance for equity funds used during construction3,163 2,670 5,759 5,115 
Interest and investment income347 204 535 428 
Miscellaneous - net(409)(527)(102)(950)
TOTAL3,101 2,347 6,192 4,593 
INTEREST EXPENSE
Interest expense23,101 21,899 44,013 44,937 
Allowance for borrowed funds used during construction(1,067)(1,075)(1,932)(2,059)
TOTAL22,034 20,824 42,081 42,878 
INCOME BEFORE INCOME TAXES114,069 48,901 169,652 103,949 
Income taxes16,584 4,111 21,764 9,101 
NET INCOME97,485 44,790 147,888 94,848 
Preferred dividend requirements518 471 1,036 941 
EARNINGS APPLICABLE TO COMMON STOCK$96,967 $44,319 $146,852 $93,907 
See Notes to Financial Statements.














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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income$147,888 $94,848 
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization113,309 104,523 
Deferred income taxes, investment tax credits, and non-current taxes accrued24,421 5,237 
Changes in assets and liabilities:
Receivables(55,237)(33,522)
Fuel inventory16,888 3,606 
Accounts payable79,801 1,530 
Taxes accrued(7,158)(4,057)
Interest accrued1,923 (1,072)
Deferred fuel costs(141,192)(72,537)
Other working capital accounts2,388 (3,285)
Provisions for estimated losses(10)314 
Other regulatory assets(143,294)43,619 
Other regulatory liabilities(14,444)(2,036)
Storm restoration costs approved for securitization recognized as regulatory asset153,383 — 
Pension and other postretirement liabilities(9,475)(11,050)
Other assets and liabilities2,536 (6,583)
Net cash flow provided by operating activities171,727 119,535 
INVESTING ACTIVITIES
Construction expenditures(304,702)(401,362)
Allowance for equity funds used during construction5,759 5,115 
Proceeds from sale of assets— 67,920 
Payment for purchase of assets— (36,534)
Litigation proceeds from settlement agreement4,134 — 
Changes in money pool receivable - net(1,643)4,601 
Changes in securitization account79 9,955 
Increase in other investments(30,000)— 
Net cash flow used in investing activities(326,373)(350,305)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt286,842 — 
Retirement of long-term debt(29,064)(170,429)
Capital contribution from parent— 85,000 
Changes in money pool payable - net(79,594)63,437 
Preferred stock dividends paid(1,024)(941)
Other33 5,132 
Net cash flow provided by (used in) financing activities177,193 (17,801)
Net increase (decrease) in cash and cash equivalents22,547 (248,571)
Cash and cash equivalents at beginning of period28 248,596 
Cash and cash equivalents at end of period$22,575 $25 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$40,816 $44,760 
Income taxes$1,085 $9,710 
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$8,224 $28 
Temporary cash investments14,351 — 
Total cash and cash equivalents22,575 28 
Securitization recovery trust account26,551 26,629 
Accounts receivable:
Customer122,672 83,797 
Allowance for doubtful accounts(2,591)(5,814)
Associated companies19,898 31,720 
Other18,714 13,404 
Accrued unbilled revenues83,535 62,241 
Total accounts receivable242,228 185,348 
Deferred fuel costs189,472 48,280 
Fuel inventory - at average cost25,824 42,712 
Materials and supplies - at average cost77,731 72,884 
Prepayments and other43,807 17,515 
TOTAL628,188 393,396 
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity275 300 
Non-utility property - at cost (less accumulated depreciation)376 376 
Other17,938 18,128 
TOTAL18,589 18,804 
UTILITY PLANT
Electric7,165,752 7,181,567 
Construction work in progress245,788 183,965 
TOTAL UTILITY PLANT7,411,540 7,365,532 
Less - accumulated depreciation and amortization2,090,728 2,049,750 
UTILITY PLANT - NET5,320,812 5,315,782 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $283,503 as of June 30, 2022 and $23,818 as of December 31, 2021)
564,627 421,333 
Other123,447 112,096 
TOTAL688,074 533,429 
TOTAL ASSETS$6,655,663 $6,261,411 
See Notes to Financial Statements.  

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies$70,373 $142,929 
Other209,234 164,981 
Customer deposits37,992 37,271 
Taxes accrued41,860 49,018 
Interest accrued20,925 19,002 
Current portion of unprotected excess accumulated deferred income taxes12,862 27,188 
Other16,845 16,120 
TOTAL410,091 456,509 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued724,033 692,496 
Accumulated deferred investment tax credits9,018 9,325 
Regulatory liability for income taxes - net135,550 144,145 
Other regulatory liabilities45,537 37,060 
Asset retirement cost liabilities8,758 8,520 
Accumulated provisions8,232 8,242 
Long-term debt (includes securitization bonds of $312,129 as of June 30, 2022 and $53,979 as of December 31, 2021)
2,612,874 2,354,148 
Other71,512 67,760 
TOTAL3,615,514 3,321,696 
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2022 and 2021
49,452 49,452 
Paid-in capital1,050,125 1,050,125 
Retained earnings1,491,731 1,344,879 
Total common shareholder's equity2,591,308 2,444,456 
Preferred stock without sinking fund38,750 38,750 
TOTAL2,630,058 2,483,206 
TOTAL LIABILITIES AND EQUITY$6,655,663 $6,261,411 
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
Common Equity
Preferred StockCommon
Stock		Paid-in
Capital		Retained
Earnings		Total
(In Thousands)
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, 202135,000 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 
Balance at December 31, 2021$38,750 $49,452 $1,050,125 $1,344,879 $2,483,206 
Net income— — — 50,403 50,403 
Preferred stock dividends— — — (518)(518)
Balance at March 31, 202238,750 49,452 1,050,125 1,394,764 2,533,091 
Net income— — — 97,485 97,485 
Preferred stock dividends— — — (518)(518)
Balance at June 30, 2022$38,750 $49,452 $1,050,125 $1,491,731 $2,630,058 
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. As discussed in “Complaints Against System Energy” below, System Energy is currently involved in proceedings at the FERC commenced by the retail regulators of its customers regarding its return on equity, its capital structure, its renewal of the sale-leaseback of 11.5% of Grand Gulf, the treatment of uncertain tax positions in rate base, the prudence of its operation of Grand Gulf, and the rates it charges under the Unit Power Sales Agreement.

Results of Operations

Net Income

Second Quarter 2022 Compared to Second Quarter 2021

System Energy experienced a net loss of $380.1 million in the second quarter 2022 primarily due to a regulatory charge of $551 million ($413 million net-of-tax) recorded in the second quarter 2022 to reflect the effects of the partial settlement agreement and offer of settlement related to pending proceedings before the FERC. See Note 2 to the financial statements herein for discussion of the partial settlement agreement and offer of settlement.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021

System Energy experienced a net loss of $348.7 million in the six months ended June 30, 2022 compared to net income of $54.2 million for the six months ended June 30, 2021 primarily due to a regulatory charge of $551 million ($413 million net-of-tax) recorded in the second quarter 2022 to reflect the effects of the partial settlement agreement and offer of settlement related to pending proceedings before the FERC. Partially offsetting the decrease in earnings was an increase in revenues resulting from changes in rate base. See Note 2 to the financial statements herein for discussion of the partial settlement agreement and offer of settlement.

Income Taxes

The effective income tax rates were 25.2% for the second quarter 2022 and 25.3% for the six months ended June 30, 2022. The differences in the effective income tax rates for the second quarter 2022 and the six months ended June 30, 2022 versus the federal statutory rate of 21% were primarily due to state income taxes.

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

The effective income tax rate was (3.1%) for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 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.


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Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2022 and 2021 were as follows:
20222021
(In Thousands)
Cash and cash equivalents at beginning of period$89,201 $242,469 
Net cash provided by (used in):
Operating activities82,645 44,451 
Investing activities(94,001)(86,677)
Financing activities56,880 (81,021)
Net increase (decrease) in cash and cash equivalents45,524 (123,247)
Cash and cash equivalents at end of period$134,725 $119,222 

Operating Activities

Net cash flow provided by operating activities increased $38.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to income tax payments of $39.1 million in 2021, timing of collections of receivables, and timing of payments to vendors, partially offset by an increase in spending of $33.5 million on nuclear refueling outages in 2022 as compared to the same period in 2021. 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 increased $7.3 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily due to:

•an increase of $61.6 million in nuclear construction expenditures due to increased spending on various nuclear projects in 2022; and
•an increase of $60.6 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

The increase was offset by money pool activity.

Decreases in System Energy’s receivable from the money pool are a source of cash flow and System Energy’s receivable from the money pool decreased by $60.3 million for the six months ended June 30, 2022 compared to increasing by $56.1 million for the six months ended June 30, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.


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Financing Activities

System Energy’s financing activities provided $56.9 million of cash for the six months ended June 30, 2022 compared to using $81 million of cash for the six months ended June 30, 2021 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; and
•a decrease of $26 million in common stock dividends and distributions. No common stock dividends or distributions were made in 2022 in order to maintain System Energy’s capital structure and in anticipation of the settlement with the MPSC.

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

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the net loss in 2022.

 June 30,
2022		December 31,
2021
Debt to capital51.8 %40.4 %
Effect of subtracting cash(4.6 %)(3.0 %)
Net debt to net capital47.2 %37.4 %

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’s receivables from the money pool were as follows:
June 30,
2022		December 31,
2021		June 30,
2021		December 31, 2020
(In Thousands)
$15,411$75,745$60,111$4,004

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

The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in June 2025. As of June 30, 2022, $93.8 million in loans were outstanding under the

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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

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion. See “System Energy Settlement with the MPSC” below for discussion of a partial settlement agreement and offer of settlement related to the pending proceedings before the FERC.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. 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 $61 million, which includes interest through June 30, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued.

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

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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 June 30, 2022 is approximately $422 million, plus interest, which is approximately $139 million through June 30, 2022. 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 June 30, 2022.

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.

LPSC 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.

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 expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, the APSC, and the City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have

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excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that: (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, the APSC, and the City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital

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structure. On all other material issues raised by the LPSC, the APSC, and the City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

In April 2022, System Energy filed cross-answering testimony in response to the FERC trial staff’s recommendations of refunds for the accumulated deferred income taxes issues and proposed tariff modifications to the Unit Power Sales Agreement for the executive incentive compensation issues. In June 2022 the FERC trial staff submitted revised answering testimony, in which it recommended additional refunds associated with the accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. Based on the testimony revisions, the FERC trial staff’s recommended refunds total $106.6 million, exclusive of any tax gross-up or FERC awarded interest. Also in June 2022, System Energy filed revised and supplemental cross-answering testimony to respond to the changes in the FERC trial staff’s testimony and oppose its revised recommendation.

In May 2022 the LPSC, the APSC, and the City Council filed rebuttal testimony. The LPSC’s testimony asserts new claims, including that: (1) certain of the sale-leaseback transaction costs may have been imprudently incurred; (2) accumulated deferred income taxes associated with sale-leaseback transaction costs should have been included in rate base; (3) accumulated deferred income taxes associated with federal investment tax credits should have been excluded from rate base; (4) monthly net operating loss accumulated deferred income taxes should have been excluded from rate base; and (5) several categories of proposed rate changes, including executive incentive compensation, air travel, industry dues, and legal costs, also warrant historical refunds. The LPSC’s rebuttal testimony argues that refunds for the alleged tariff violations and other claims must be calculated by rerunning the Unit Power Sales Agreement formula rate; however, it includes estimates of refunds associated with some, but not all, of its claims, totaling $286 million without interest. The City Council’s rebuttal testimony also proposes a new, alternate theory and claim for relief regarding System Energy’s participation in the Entergy System money pool, under which it calculates estimated refunds of approximately $51.7 million. The APSC’s rebuttal testimony agrees with the LPSC’s direct testimony that retained earnings should be adjusted in a comprehensive refund calculation. The testimony quantifies the estimated impacts of three issues: (1) a $1.5 million reduction in the revenue requirement under the Unit Power Sales Agreement if System Energy’s borrowings from the money pool are included in short-term debt; (2) a $1.9 million reduction in the revenue requirement if System Energy’s allocated share of money pool earnings are credited through the Unit Power Sales Agreement; and (3) a $1.9 million reduction in the revenue requirement for every $50 million of refunds ordered in a given year, without interest.

In June 2022 a new procedural schedule was adopted, providing for additional rounds of testimony, for the hearing to begin in September 2022, and for the initial decision to be issued in February 2023. In July 2022, System Energy filed responsive rebuttal testimony responding to the new claims in the LPSC’s and the City Council’s rebuttal testimony. Also in July 2022 the LPSC filed supplemental rebuttal testimony responding to System Energy’s revised cross-answering testimony.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million in refunds, excluding interest

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which will be calculated after a FERC order is issued; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

System Energy Settlement with the MPSC

In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorializes the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered. The settlement therefore limits System Energy’s overall refund exposure associated with the identified proceedings because they will be resolved completely as between the Entergy parties and the MPSC.

The FERC proceedings that are resolved as between the Entergy parties and the MPSC include the Return on Equity and Capital Structure Complaints, the Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue, the Unit Power Sales Agreement Complaint, and the Grand Gulf Prudence Complaint, all of which are discussed in Note 2 to the financial statements in the Form 10-K, and updated above. They also include the proceedings concerning System Energy’s return of excess accumulated deferred income taxes after the Tax Cuts and Jobs Act and the proceedings established to address System Energy’s October 2020 and December 2020 Federal Power Act section 205 filings to provide credits to customers related to the IRS’s decision as to the uncertain decommissioning tax position, also as all discussed in Note 2 to the financial statements in the Form 10-K. The settlement also resolves the MPSC’s involvement in the formal challenge filed by the retail regulators of System Energy’s customers in connection with the implementation of the Unit Power Sales Agreement annual formula rate protocols for the 2020 test year, which is discussed above.

The settlement provides for a black-box refund of $235 million from System Energy to Entergy Mississippi, which will be paid within 120 days of the settlement’s effective date (either the date of the FERC approval of the settlement without material modification, or the date that all settling parties agree to accept modifications or otherwise modify the settlement in response to a proposed material modification by the FERC). In addition, beginning with the July 2022 service month, the settlement provides for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates.

The settlement is expressly contingent upon the approval of the FERC and the MPSC. It was approved by the MPSC in June 2022. The remaining retail regulators of Entergy’s utility operating company purchasers under the Unit Power Sales Agreement (the APSC, the LPSC, and the City Council) may elect to join the settlement. If all of them elect to do so under the terms of the settlement, then the total black-box refund payment by System Energy would be $588.25 million, and the prospective rate adjustments would apply to all purchasers under the Unit Power Sales Agreement.

If the FERC approves the settlement in accordance with its terms, then it will become binding upon the Entergy parties and the MPSC even if no additional retail regulators elect to join the settlement. The settlement will have no effect on the rights of non-settling parties to the identified FERC proceedings.

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System Energy previously recorded a provision and associated liability of $37 million for elements of the applicable litigation. In June 2022, System Energy recorded a regulatory charge of $551 million ($413 million net-of-tax), increasing the regulatory liability to $588 million, which consists of $235 million for the settlement with the MPSC and $353 million for potential future refunds to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. In August 2022 comments on the settlement were filed by the APSC, the LPSC, the City Council, the FERC trial staff, and a group that refers to itself as the Louisiana Stakeholders, which are three entities that intervened in the Grand Gulf Prudence Complaint proceeding but not any other proceedings that are part of the settlement. The APSC, the LPSC, and the City Council do not intend to join the settlement, but they do not oppose its approval as between the MPSC and the Entergy parties. The FERC trial staff concludes that the settlement is fair, reasonable, and in the public interest. The Louisiana Stakeholders oppose the settlement, alleging it does not resolve the issues raised in the Grand Gulf Prudence Complaint proceeding. Reply comments will be filed later in August 2022.

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 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. See “Qualified Pension and Other Postretirement Benefits” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the discussion of qualified pension and other postretirement benefits.

New Accounting Pronouncements

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

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF OPERATIONS
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
Three Months EndedSix Months Ended
2022202120222021
(In Thousands)(In Thousands)
OPERATING REVENUES
Electric$163,872 $161,313 $305,248 $279,059 
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale11,610 14,073 19,533 30,932 
Nuclear refueling outage expenses5,320 6,792 11,247 13,510 
Other operation and maintenance54,685 58,047 98,589 100,007 
Decommissioning10,016 9,625 19,933 19,154 
Taxes other than income taxes7,150 6,968 15,001 13,793 
Depreciation and amortization37,777 25,768 67,700 53,962 
Other regulatory charges (credits) - net527,515 (17,550)518,991 (6,000)
TOTAL654,073 103,723 750,994 225,358 
OPERATING INCOME (LOSS)(490,201)57,590 (445,746)53,701 
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction2,581 1,355 4,628 2,466 
Interest and investment income(8,959)(2,410)(3,727)25,032 
Miscellaneous - net(2,741)(7,886)(4,380)(9,910)
TOTAL(9,119)(8,941)(3,479)17,588 
INTEREST EXPENSE
Interest expense9,112 9,579 18,593 19,114 
Allowance for borrowed funds used during construction(409)(229)(736)(417)
TOTAL8,703 9,350 17,857 18,697 
INCOME (LOSS) BEFORE INCOME TAXES(508,023)39,299 (467,082)52,592 
Income taxes(127,875)8,969 (118,366)(1,602)
NET INCOME (LOSS)($380,148)$30,330 ($348,716)$54,194 
See Notes to Financial Statements.


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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
20222021
(In Thousands)
OPERATING ACTIVITIES
Net income (loss)($348,716)$54,194 
Adjustments to reconcile net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization104,296 101,640 
Deferred income taxes, investment tax credits, and non-current taxes accrued(124,202)(3,052)
Changes in assets and liabilities:
Receivables(14,753)(15,877)
Accounts payable(27,368)(3,449)
Taxes accrued(2,664)(27,698)
Interest accrued(247)(1,102)
Other working capital accounts(41,234)442 
Other regulatory assets(22,768)60,949 
Other regulatory liabilities338,280 49,033 
Pension and other postretirement liabilities(7,494)(12,243)
Other assets and liabilities229,515 (158,386)
Net cash flow provided by operating activities82,645 44,451 
INVESTING ACTIVITIES
Construction expenditures(100,953)(38,268)
Allowance for equity funds used during construction4,628 2,466 
Nuclear fuel purchases(77,704)(11,039)
Proceeds from the sale of nuclear fuel18,845 12,754 
Proceeds from nuclear decommissioning trust fund sales177,584 418,042 
Investment in nuclear decommissioning trust funds(176,735)(414,525)
Changes in money pool receivable - net60,334 (56,107)
Net cash flow used in investing activities(94,001)(86,677)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt556,696 453,981 
Retirement of long-term debt(499,816)(509,002)
Common stock dividends and distributions paid— (26,000)
Net cash flow provided by (used in) financing activities56,880 (81,021)
Net increase (decrease) in cash and cash equivalents45,524 (123,247)
Cash and cash equivalents at beginning of period89,201 242,469 
Cash and cash equivalents at end of period$134,725 $119,222 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized$19,454 $29,231 
Income taxes$— $39,085 
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash$77 $87 
Temporary cash investments134,648 89,114 
Total cash and cash equivalents134,725 89,201 
Accounts receivable:
Associated companies75,557 118,977 
Other4,842 7,003 
Total accounts receivable80,399 125,980 
Materials and supplies - at average cost127,154 127,093 
Deferred nuclear refueling outage costs47,789 10,123 
Prepayments and other5,376 1,870 
TOTAL395,443 354,267 
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds1,138,811 1,385,254 
TOTAL1,138,811 1,385,254 
UTILITY PLANT
Electric5,442,584 5,362,494 
Construction work in progress79,596 97,968 
Nuclear fuel193,253 171,438 
TOTAL UTILITY PLANT5,715,433 5,631,900 
Less - accumulated depreciation and amortization3,423,021 3,396,136 
UTILITY PLANT - NET2,292,412 2,235,764 
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets418,314 395,546 
Other1,781 1,793 
TOTAL420,095 397,339 
TOTAL ASSETS$4,246,761 $4,372,624 
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2022 and December 31, 2021
(Unaudited)
20222021
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt$250,030 $50,329 
Accounts payable:
Associated companies13,797 23,682 
Other50,948 62,573 
Taxes accrued30,254 32,918 
Interest accrued11,467 11,714 
Other4,100 4,101 
TOTAL360,596 185,317 
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued260,035 382,931 
Accumulated deferred investment tax credits42,364 43,003 
Regulatory liability for income taxes - net109,309 113,165 
Other regulatory liabilities1,087,080 744,944 
Decommissioning1,027,536 1,007,603 
Pension and other postretirement liabilities68,610 76,104 
Long-term debt548,585 690,967 
Other2 37,230 
TOTAL3,143,521 3,095,947 
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2022 and 2021
951,850 951,850 
Retained earnings (accumulated deficit)(209,206)139,510 
TOTAL742,644 1,091,360 
TOTAL LIABILITIES AND EQUITY$4,246,761 $4,372,624 
See Notes to Financial Statements.

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STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2022 and 2021
(Unaudited)
Common Equity
Common
Stock		Retained
Earnings (Accumulated Deficit)		Total
(In Thousands)
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, 2021951,850 131,560 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 
Balance at December 31, 2021$951,850 $139,510 $1,091,360 
Net income— 31,432 31,432 
Balance at March 31, 2022951,850 170,942 1,122,792 
Net loss— (380,148)(380,148)
Balance at June 30, 2022$951,850 ($209,206)$742,644 
See Notes to Financial Statements.


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ENTERGY CORPORATION AND SUBSIDIARIES
PART II. OTHER INFORMATION

Item 1.  Legal Proceedings

See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy.  Also see Notes 1 and 2 to the financial statements herein and “Item 5, Other Information, Environmental Regulation” below for updates regarding environmental proceedings and regulation.

Item 1A.  Risk Factors

See the risk factors discussed in "Part I, Item 1A. RISK FACTORS" in the Form 10-K, which could materially affect Entergy's and its Registrant Subsidiaries' business, financial condition, or future results. The information set forth in this report, including the risk factor presented below, updates and should be read in conjunction with the risk factors and information disclosed in the Form 10-K.

The completion of capital projects, including the construction of power generation facilities, and other capital improvements involve substantial risks. Should such efforts be unsuccessful, the financial condition, results of operations, or liquidity of Entergy and the Utility operating companies could be materially affected.

Entergy’s and the Utility operating companies’ ability to complete capital projects, including the construction of power generation facilities, or make other capital improvements, in a timely manner and within budget is contingent upon many variables and subject to substantial risks. These variables include, but are not limited to, project management expertise, escalating costs for materials, labor, and environmental compliance, reliance on suppliers for timely and satisfactory performance, and pandemic-related delays and cost increases. Delays in obtaining permits, shortages in materials and qualified labor, levels of public support or opposition, suppliers and contractors not performing as expected or required under their contracts and/or experiencing financial problems that inhibit their ability to fulfill their obligations under contracts, changes in the scope and timing of projects, poor quality initial cost estimates from contractors, the inability to raise capital on favorable terms, changes in commodity prices affecting revenue, fuel costs, or materials costs, downward changes in the economy, changes in law or regulation, including environmental compliance requirements, trade and tariff issues associated with imported solar panels, supply chain delays or disruptions, and other events beyond the control of the Utility operating companies may occur that may materially affect the schedule, cost, and performance of these projects. If these projects or other capital improvements are significantly delayed or become subject to cost overruns or cancellation, Entergy and the Utility operating companies could incur additional costs and termination payments, or face increased risk of potential write-off of the investment in the project. In addition, the Utility operating companies could be exposed to higher costs and market volatility, which could affect cash flow and cost recovery, should their respective regulators decline to approve the construction of the project or new generation needed to meet the reliability needs of customers at the lowest reasonable cost.

For further information regarding capital expenditure plans and other uses of capital in connection with capital projects, including the potential construction and/or purchase of additional generation supply sources within the Utility operating companies’ service territory, see the “Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital” section of Management’s Financial Discussion and Analysis for Entergy herein and in the Form 10-K and the “Liquidity and Capital Resources - Uses of Capital” section of Management’s Financial Discussion and Analysis in the Form 10-K and the “Liquidity and Capital Resources - Uses and Sources of Capital” section of Management’s Financial Discussion and Analysis herein for each of the Registrant Subsidiaries.


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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)
4/01/2022-4/30/2022— $— — $350,052,918 
5/01/2022-5/31/2022— $— — $350,052,918 
6/01/2022-6/30/2022— $— — $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 2022, Entergy withheld 79,738 shares of its common stock at $110.35 per share, 77,207 shares of its common stock at $111.16 per share, 35,940 shares of its common stock at $111.77 per share, 1,219 shares of its common stock at $109.01 per share, 577 shares of its common stock at $106.62 per share, 232 shares of its common stock at $110.77 per share, 87 shares of its common stock at $109.01 per share, and 82 shares of its common stock at $111.47 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 2022 filings with the NRC were made reporting on decommissioning funding for Palisades and the Big Rock Point dry fuel storage facility. Those reports showed that decommissioning funding for those facilities met the NRC’s financial assurance requirements.


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Environmental Regulation

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

National Ambient Air Quality Standards

See the Form 10-K for discussion of the National Ambient Air Quality Standards (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. In February 2022 the EPA issued a proposed rule revoking the 2020 rule and determining, again, that it is “appropriate and necessary” to regulate hazardous air pollutants. The EPA is seeking additional information, which it could use to further tighten the standard. 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 April 2022 the EPA published a rule to address interstate transport for the 2015 ozone NAAQS and which will increase the stringency of the CSAPR program in all four of the states where the Utility operating companies operate. If finalized as proposed, the rule will significantly reduce emission allowances and would likely require the installation of post-combustion nitrogen oxides (NOx) emissions controls on any coal or large legacy gas units that will operate beyond 2026 and are not currently equipped with such controls. Fifteen Entergy-owned units, totaling approximately 9,370 MW of total unit capacity, are identified by the EPA for selective catalytic reduction retrofits. If all of these units were retrofitted as proposed, the EPA estimates that the capital cost is expected to be approximately $1.6 billion. Additionally the EPA is proposing controls on certain non-electric generating NOx sources. Since releasing the proposed rule, the price for Group 3 allowances has increased significantly, reaching $40,000 per allowance in late June 2022. Comments on the proposed rule were due in June 2022. MISO, other impacted regional transmission organizations, and various state public service commissions all filed comments expressing reliability concerns if the rule is finalized as proposed. Entergy filed individual comments which assert, in addition to other issues, that the EPA’s proposal represents over-control of the Entergy units in Arkansas and Mississippi; the EPA should consider an alternative approach or provide flexibility for units with a limited remaining useful life; the EPA should consult with regional transmission organizations to determine the reliability impacts of the proposed rule; and the EPA should consider and incorporate current economic trends, including inflation, into any benefit-costs analysis supporting the rule.

Regional Haze

As discussed in the Form 10-K, the second planning period (2018-2028) for the regional haze program required states to examine sources for impacts on visibility and to prepare State Implementation Plans (SIPs) by July 31, 2021 which the Arkansas Department of Energy and Environment, Division of Environmental Quality (ADEQ) did not meet. The ADEQ released a draft proposed SIP in February 2022. The ADEQ reviewed Entergy’s Independence plant, but determined that additional air emission controls would not be cost-effective considering the facility’s commitment to cease coal-fired combustion by December 31, 2030. The ADEQ is expected to finalize this SIP and submit to the EPA for review by the end of 2022.

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The Texas Commission on Environmental Quality has completed its second-planning period SIP and submitted it to the EPA for review. There were no Entergy sources selected for additional emission controls. The Mississippi Department of Environmental Quality continues to develop its SIP, but there are no Entergy sources that are expected to be impacted.

In April 2022 the EPA announced that states have until August 15, 2022 to submit their SIPs in order to avoid a Finding of Failure to Submit which the EPA intends to issue by August 31, 2022.

Greenhouse Gas Emissions

As discussed in the Form 10-K, in July 2019 the EPA released the Affordable Clean Energy Rule (ACE), which applies only to existing coal-fired electric generating units. The ACE determines that heat rate improvements are the best system of emission reductions and lists six candidate technologies for consideration by states at each coal unit. The rule and associated rulemakings by the EPA replace the Obama administration’s Clean Power Plan, which established national emissions performance rates for existing fossil-fuel fired steam electric generating units and combustion turbines. The ACE rule provides states discretion in determining how the best system for emission reductions applies to individual units, including through the consideration of technical feasibility and the remaining useful life of the facility. In January 2021 the U.S. Court of Appeals for the D.C. Circuit vacated 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 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, 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. In October 2021 the United States Supreme Court agreed to hear a challenge to the already vacated ACE rule. In June 2022 the United States Supreme Court held that the EPA could not use generation shifting as the best system of emission reduction under Section 111(d) of the Clean Air Act. The EPA does still have the authority to regulate greenhouse gas emissions, but those emissions reductions must be technology based. Despite the decision, the EPA appears to be moving forward with a new proposal, which is expected in 2023, to regulate greenhouse gas emissions from new and existing electric generating units.

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) became effective, narrowing the scope of Clean Water Act jurisdiction, as compared to a 2015 definition which had been stayed by several federal courts. 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 (Corps) subsequently issued a statement that the agencies would revert to pre-2015 regulations pending a new rulemaking. In December 2021, the EPA and the Corps proposed a revised definition of waters of the United States by repealing the NWPR and codifying a definition that reflects the pre-2015 regulatory regime as interpreted by several United States Supreme Court decisions. Comments on the proposed rule were due in February 2022. In January 2022, despite pending rulemaking, the United States Supreme Court agreed to hear a case regarding the proper test under previous Supreme Court decisions for determining jurisdiction of waters of the United States. The EPA intends to complete the rulemaking in two phases: finalize the proposed rulemaking in August 2022 and then subsequent rulemaking in 2023 that refines the rule as necessary based on the United States Supreme Court’s decision.


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Retail Rate Regulation

The following replaces the information provided in footnote (b) to the table providing rate base and other information in the “Retail Rate Regulation” section of Part I, Item 1 of the Form 10-K relating to the Entergy Louisiana (electric) rate base amount of $13.6 billion: (b) Based on December 31, 2020 test year and includes approximately $800 million for the Lake Charles Power Station and excludes $300 million for the Washington Parish Energy Center, included in the capacity rider, $100 million of transmission plant investment, included in the transmission rider, and $300 million of distribution investment, included in the distribution rider.

Item 6.  Exhibits
4(a) -
4(b) -
*4(c) -
*4(d) -
*4(e) -
*4(f) -
4(g) -
10(a) -
*31(a) -
*31(b) -
*31(c) -
*31(d) -
*31(e) -
*31(f) -

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*31(g) -
*31(h) -
*31(i) -
*31(j) -
*31(k) -
*31(l) -
*31(m) -
*31(n) -
**32(a) -
**32(b) -
**32(c) -
**32(d) -
**32(e) -
**32(f) -
**32(g) -
**32(h) -
**32(i) -
**32(j) -
**32(k) -
**32(l) -
**32(m) -
**32(n) -
*101 INS -
Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101 SCH -
Inline XBRL Schema Document.
*101 PRE -
Inline XBRL Presentation Linkbase Document.
*101 LAB -
Inline XBRL Label Linkbase Document.
*101 CAL -
Inline XBRL Calculation Linkbase Document.
*101 DEF -
Inline XBRL Definition Linkbase Document.
*104 -
Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibits 101).
___________________________
Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.
*Filed herewith.
**Furnished, not filed, herewith.

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.  The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.
ENTERGY CORPORATION
ENTERGY ARKANSAS, LLC
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, LLC
ENTERGY NEW ORLEANS, LLC
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC.
/s/ Kimberly A. Fontan
Kimberly A. Fontan
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

Date:    August 4, 2022


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