0000065984etr:GovernmentalMemberus-gaap:0000065984us-gaap:ElectricityMemberetr:EntergyArkansasMember2020-04-012020-06-30NonCustomerMemberetr:EntergyMississippiMember2022-04-012022-06-30
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
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| (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, 20212022
OR
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13
OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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| For the transition period from ____________ to ____________ |
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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. |
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| 1-11299 | ENTERGY CORPORATION | | 1-35747 | ENTERGY 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 |
| 72-1229752 | | | 82-2212934 |
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| 1-10764 | ENTERGY ARKANSAS, LLC | | 1-34360 | ENTERGY TEXAS, INC. |
| (a Texas limited liability company) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000 | | | (a Texas corporation) 10055 Grogans Mill Road2107 Research Forest Drive
The Woodlands, Texas 77380 Telephone (409) 981-2000 |
| 83-1918668 | | | 61-1435798 |
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| 1-32718 | ENTERGY LOUISIANA, LLC | | 1-09067 | SYSTEM 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 |
| 47-4469646 | | | 72-0752777 |
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| 1-31508 | ENTERGY 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:
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| Registrant | Title of Class | Trading
Symbol | Name of Each Exchange
on Which Registered |
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| Entergy Corporation | Common Stock, $0.01 Par Value | ETR | New York Stock Exchange |
| Common Stock, $0.01 Par Value | ETR | NYSE Chicago, Inc. |
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| Entergy Arkansas, LLC | Mortgage Bonds, 4.875% Series due September 2066 | EAI | New York Stock Exchange |
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| Entergy Louisiana, LLC | Mortgage Bonds, 4.875% Series due September 2066 | ELC | New York Stock Exchange |
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| Entergy Mississippi, LLC | Mortgage Bonds, 4.90% Series due October 2066 | EMP | New York Stock Exchange |
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| 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 |
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| Entergy Texas, Inc. | 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share) | ETI/PR | New York Stock Exchange |
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.
Yes ☑ No ☐
Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes ☑ No ☐
Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.
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| Large accelerated filer | | Accelerated
filer | | Non-accelerated filer | | Smaller
reporting
company | | Emerging
growth
company |
| Entergy Corporation | ü | | | | | | | | |
| Entergy Arkansas, LLC | | | | | ü | | | | |
| Entergy Louisiana, LLC | | | | | ü | | | | |
| Entergy Mississippi, LLC | | | | | ü | | | | |
| Entergy New Orleans, LLC | | | | | ü | | | | |
| Entergy Texas, Inc. | | | | | ü | | | | |
| System Energy Resources, Inc. | | | | | ü | | | | |
If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑
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| Common Stock Outstanding | | Outstanding at July 30, 202129, 2022 |
| Entergy Corporation | ($0.01 par value) | 200,954,557203,417,995 |
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, 20202021 and the Quarterly Report on Form 10-Q for the quarter ended March 31, 2021,2022, filed by the individual registrants with the SEC, and should be read in conjunction therewith.
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| Part I. Financial Information |
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| Entergy Corporation and Subsidiaries | |
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| Notes to Financial Statements | |
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| Entergy Arkansas, LLC and Subsidiaries | |
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| Entergy Louisiana, LLC and Subsidiaries | |
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| Entergy Mississippi, LLC and Subsidiaries | |
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| Entergy New Orleans, LLC and Subsidiaries | |
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Entergy Texas, Inc. and Subsidiaries | |
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| Entergy Texas, Inc. and Subsidiaries | |
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| System Energy Resources, Inc. | |
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| 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 (a) 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;
•continuing long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;
•regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the benefits of continued MISO participation, the effect of current or projected MISO market rules and market and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, the MISO-wide base rate of return on equity allowed or any MISO-related charges and credits required by the FERC, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;
•changes in utility regulation, including with respect to retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent return on equity criteria, transmission reliability requirements or market power criteria by the FERC or the U.S. Department of Justice;
•changes in the regulation or regulatory oversight of Entergy’s owned or operated nuclear generating facilities, and nuclear materials and fuel, including with respect to the planned shutdown and sale of Palisades, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and fuel;
•resolution of pending or future applications, and related regulatory proceedings and litigation, for license modifications or other authorizations required of nuclear generating facilities and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;
•the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at Entergy’s nuclear generating facilities;
•increases in costs and capital expenditures that could result from changing regulatory requirements, 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;
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;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, (including from Hurricane Laura, Hurricane Delta, and Hurricane Zeta), ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance, as well as any related unplanned outages;
•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, and industry self-insurance programs;
•effects of climate change, including the potential for increases in extreme weather events and sea levels or coastal land and wetland loss;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 execute share repurchase programs, and fund investments and acquisitions;
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;
FORWARD-LOOKING INFORMATION (Concluded)
•changes in inflation and interest rates;
•the effects of litigation and government investigations or proceedings;
•changes in technology, including (i) Entergy’s ability to implement new or emerging technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, renewable energy, energy efficiency, demand side management and other measures that reduce load and government policies incentivizing development of the foregoing, and (iii) competition from other companies offering products and services to Entergy’s customers based on new or emerging technologies or alternative sources of generation;
•Entergy’s ability to effectively formulate and implement plans to reduce its carbon emission rate and aggregate carbon emissions, including its commitment to achieve net-zero carbon emissions by 2050, and the potential impact on its business of attempting to achieve such objectives;
•the effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;
•the effects of a global 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 decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by mid-2022, including the implementation of the planned shutdown and sale of Palisades;
•the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments;
•the potential for the factors listed herein to lead to the impairment of long-lived assets; and
•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that Entergythey may undertake.
DEFINITIONS
Certain abbreviations or acronyms used in the text and notes are defined below:
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| Abbreviation or Acronym | Term |
| |
| ALJ | Administrative Law Judge |
| ANO 1 and 2 | Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas |
| APSC | Arkansas Public Service Commission |
| ASU | Accounting Standards Update issued by the FASB |
| Board | Board of Directors of Entergy Corporation |
| Cajun | Cajun Electric Power Cooperative, Inc. |
| capacity factor | Actual plant output divided by maximum potential plant output for the period |
| City Council | Council of the City of New Orleans, Louisiana |
| 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 customerscustomers. 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, 20202021 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 |
DEFINITIONS (Continued)
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| Abbreviation or Acronym | Term |
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| GWh | Gigawatt-hour(s), which equals one million kilowatt-hours |
| HLBV | Hypothetical 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 |
DEFINITIONS (Continued)
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Abbreviation or Acronym | Term |
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| 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 |
Net MW in operation | Installed capacity owned and operated |
| 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 |
Pilgrim | Pilgrim Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2019 and was sold in August 2019 |
| PPA | Purchased power agreement or power purchase agreement |
| PUCT | Public Utility Commission of Texas |
| Registrant Subsidiaries | Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. |
| River Bend | River Bend Station (nuclear), owned by Entergy Louisiana |
| SEC | Securities and Exchange Commission |
| System Agreement | Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources. The agreement terminated effective August 2016. |
System Energy | System Energy Resources, Inc. |
TWh | Terawatt-hour(s), which equals one billion kilowatt-hours |
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DEFINITIONS (Concluded)
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| Abbreviation or Acronym | Term |
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| 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 |
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.
•The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business.
•The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown and sale of each of the Entergy Wholesale CommoditiesCommodities 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.
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic and its effects on Entergy’s business.
Hurricane Laura, Hurricane Delta, and Hurricane Zeta
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of the Utility’s service territories in Louisiana, including New Orleans, Texas, and to a lesser extent, in Arkansas and Mississippi. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana, Entergy New Orleans, and Entergy Texas.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for February 2021 for Entergy were approximately $720 million, including $145 million for Entergy Arkansas, $285 million for Entergy Louisiana, $65 million for Entergy Mississippi, $35 million for Entergy New Orleans, and $185 million for Entergy Texas. This compares to fuel and purchased power costs for February 2020 for Entergy of $245 million, including $40 million for Entergy Arkansas, $95 million for Entergy Louisiana, $35 million for Entergy Mississippi, $25 million for Entergy New Orleans, and $50 million for Entergy Texas. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana and Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at the Utility operating companies.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Results of Operations
Second Quarter 20212022 Compared to Second Quarter 20202021
Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the second quarter 20212022 to the second quarter 20202021 showing how much the line item increased or (decreased) in comparison to the prior period:
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Utility | | Entergy
Wholesale
Commodities | |
Parent & Other (a) | |
Entergy | |
Utility | | Entergy
Wholesale
Commodities | |
Parent & Other (a) | |
Entergy |
| | | (In Thousands) | | | (In Thousands) |
| 2020 Net Income (Loss) Attributable to Entergy Corporation | | $344,869 | | | $84,631 | | | ($68,967) | | | $360,533 | | |
| 2021 Net Income (Loss) Attributable to Entergy Corporation | | 2021 Net Income (Loss) Attributable to Entergy Corporation | | $325,903 | | | ($275,195) | | | ($56,682) | | | ($5,974) | |
| | Operating revenues | Operating revenues | | 460,324 | | | (51,053) | | | 11 | | | 409,282 | | Operating revenues | | 632,884 | | | (59,723) | | | (35) | | | 573,126 | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 284,683 | | | 376 | | | — | | | 285,059 | | Fuel, fuel-related expenses, and gas purchased for resale | | 18,570 | | | 7,317 | | | (5) | | | 25,882 | |
| Purchased power | Purchased power | | 32,515 | | | 7,895 | | | — | | | 40,410 | | Purchased power | | 310,321 | | | 7,930 | | | 5 | | | 318,256 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | (29,891) | | | — | | | — | | | (29,891) | | Other regulatory charges (credits) - net | | 816,201 | | | — | | | — | | | 816,201 | |
| Other operation and maintenance | Other operation and maintenance | | 102,213 | | | (56,992) | | | (364) | | | 44,857 | | Other operation and maintenance | | 34,446 | | | (40,848) | | | 2,999 | | | (3,403) | |
| Asset write-offs, impairments, and related charges | | — | | | 335,317 | | | — | | | 335,317 | | |
| Asset write-offs, impairments, and related charges (credits) | | Asset write-offs, impairments, and related charges (credits) | | — | | | (506,158) | | | — | | | (506,158) | |
| Taxes other than income taxes | Taxes other than income taxes | | 5,654 | | | (8,346) | | | (43) | | | (2,735) | | Taxes other than income taxes | | 19,567 | | | (3,239) | | | 5 | | | 16,333 | |
| Depreciation and amortization | Depreciation and amortization | | 28,904 | | | (11,040) | | | (88) | | | 17,776 | | Depreciation and amortization | | 34,891 | | | (11,172) | | | (505) | | | 23,214 | |
| | Other income (deductions) | Other income (deductions) | | (45,535) | | | (152,885) | | | 4,205 | | | (194,215) | | Other income (deductions) | | (5,315) | | | (59,299) | | | (10,647) | | | (75,261) | |
| Interest expense | Interest expense | | 10,085 | | | (2,809) | | | 1,444 | | | 8,720 | | Interest expense | | 10,621 | | | (2,288) | | | 5,152 | | | 13,485 | |
| Other expenses | Other expenses | | 1,942 | | | (12,350) | | | — | | | (10,408) | | Other expenses | | (596) | | | (29,527) | | | — | | | (30,123) | |
| Income taxes | Income taxes | | (2,350) | | | (96,163) | | | (9,018) | | | (107,531) | | Income taxes | | (443,064) | | | 96,929 | | | 4,908 | | | (341,227) | |
| Preferred dividend requirements of subsidiaries and noncontrolling interest | | Preferred dividend requirements of subsidiaries and noncontrolling interest | | (224) | | | — | | | (48) | | | (272) | |
| | 2021 Net Income (Loss) Attributable to Entergy Corporation | | $325,903 | | | ($275,195) | | | ($56,682) | | | ($5,974) | | |
| 2022 Net Income (Loss) Attributable to Entergy Corporation | | 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 hereinin the Form 10-K for further discussion of the sale of the Indian Point Energy Center.
Second quarter 2020 results of operations include gains of $225 million (pre-tax) on Entergy Wholesale Commodities’ nuclear decommissioning trust fund investments reflecting the equity market rebound from the March 2020 decline associated with the COVID-19 pandemic.See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.
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 20212022 to the second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $2,2132,673 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 354376 | |
| Volume/weather | 140 | |
| Storm restoration carrying costs | 59 | |
| Retail electric price | 9658 | |
Volume/weather | 10 | |
20212022 operating revenues | $2,6733,306 | |
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 withJanuary 2022;
•an increase in Entergy Louisiana’s formula rate plan revenues, including increases in the first billing cycle of Maydistribution and transmission recovery mechanisms, effective September 2021;
•increases in Entergy Louisiana’s overall formula rate plan revenues, including an increase in the transmission recovery mechanism effective September 2020, and an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center;
•an increase in Entergy Mississippi’s formula rate plan rates effective in part, with the first billing cycle ofJuly 2021 and April 2021;2022;
•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs,rates effective November 2020;2021; and
•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021,2022 and an increase in the distribution cost recovery factor rider effective March 2021,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.
The volume/weather variance is primarily due to an increase of 777 GWh, or 3%, in billed electricity usage primarily due to an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage primarily due to an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries, and an increase in demand from cogeneration customers. The increase was partially offset by a decrease in usage from residential customers primarily due to the impact that the COVID-19 pandemic had on prior year usage. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the COVID-19 pandemic.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
BilledTotal electric energy sales for Utility for the three months ended June 30,2021 2022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 7,361 | | | 7,759 | | | (5) | | Residential | 9,493 | | | 8,487 | | | 12 | |
| Commercial | Commercial | 6,370 | | | 6,071 | | | 5 | | Commercial | 7,203 | | | 6,731 | | | 7 | |
| Industrial | Industrial | 12,690 | | | 11,846 | | | 7 | | Industrial | 13,480 | | | 12,640 | | | 7 | |
| Governmental | Governmental | 602 | | | 570 | | | 6 | | Governmental | 641 | | | 616 | | | 4 | |
| Total retail | Total retail | 27,023 | | | 26,246 | | | 3 | | Total retail | 30,817 | | | 28,474 | | | 8 | |
| Sales for resale | Sales for resale | 4,716 | | | 3,111 | | | 52 | | Sales for resale | 3,920 | | | 4,716 | | | (17) | |
| Total | Total | 31,739 | | | 29,357 | | | 8 | | Total | 34,737 | | | 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 $200$149 million for the second quarter 20202021 to $149$89 million for the second quarter 20212022 primarily due to the shutdown of Palisades in May 2022 and Indian Point 3 in April 2021 and lower realized wholesale energy and capacity prices including the effect of the additional PPA entered into with Consumers Energy covering the period from April 2022 to final shutdown in May 2022 at a lower rate than the original PPA. See Note 19 to the financial statements in the Form 10-K for further discussion of Indian Point 2 in April 2020.the Palisades PPA.
Following are key performance measures for Entergy Wholesale Commodities for the second quarters2021 2022 and 2020:2021:
| | | | | | | | | | | |
| 2021 | | 2020 |
| Owned capacity (MW) (a) | 1,205 | | 2,246 |
| GWh billed | 2,687 | | 4,958 |
| | | |
| Entergy Wholesale Commodities Nuclear Fleet | | | |
| Capacity factor | 94% | | 96% |
| GWh billed | 2,356 | | 4,580 |
| Average energy price ($/MWh) | $48.75 | | $35.48 |
| Average capacity price ($/kW-month) | $0.32 | | $2.33 |
| | | |
| | | |
| | | |
| | | |
The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the second quarters of 2021 and 2020. | | | | | | | | | | | |
| 2022 | | 2021 |
| Owned capacity (MW) (a) | 394 | | 1,205 |
| GWh billed | 1,371 | | 2,687 |
| | | |
| Entergy Wholesale Commodities Nuclear Fleet (b) | | | |
| Capacity factor | 81% | | 94% |
| GWh billed | 975 | | 2,356 |
| Average energy price ($/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 1,041811 MW Indian Point 3Palisades plant in AprilMay 2022.
(b)The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the second quarters 2022 and 2021.
Other Income Statement Items
Utility
Other operation and maintenance expenses increased from $589 million for the second quarter 2020 to $691 million for the second quarter 2021 primarily due to:
•an increase of $16 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020 and higher expenses associated with plants placed in service, including the New Orleans Power Station, which began commercial operation in May
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
2020;Other Income Statement Items
Utility
Other operation and maintenance expenses increased from $691 million for the Washington Parish Energy Center, purchased in November 2020; andsecond quarter 2021 to $726 million for the Montgomery County Power Station, which began commercial operation in January 2021;
•an increase of $15 million in nuclear generation expensessecond quarter 2022 primarily due to higher nuclear labor costs and a higher scope of work performed in 2021 as compared to 2020;to:
•an increase of $14$10 million in compensation and benefits costspower delivery expenses primarily due to lower healthcare claims activityhigher reliability costs and higher safety and training costs, partially offset by a decrease in 2020meter reading expenses as a result of the COVID-19 pandemic,deployment of advanced metering systems;
•an increase of $6 million in healthcare cost rates,energy efficiency expenses due to the timing of recovery from customers and higher energy efficiency costs;
•an increase of $5 million in net periodic pension and other postretirement benefitscustomer service center support costs as a resultprimarily due to higher contract costs;
•an increase of a decrease$5 million in bad debt expense primarily due to the discount rate used to valuedeferral in 2021 of bad debt expense resulting from the benefit liabilities.COVID-19 pandemic. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 62 to the financial statements herein and Note 11 to the financial statements in the Form 10-K for further discussion of pensionregulatory activity associated with the COVID-19 pandemic; and other postretirement benefit costs;
•an increase of $14$2 million in distribution operations expensesloss provisions.
Taxes other than income taxes increased primarily due to increases in ad valorem taxes resulting from higher distribution reliability costsassessments and higher vegetation maintenance costs;
•the effects of recordingincreases in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $8 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;
•an increase of $7 million in information technology costs primarily due to higher contract costs and higher costs associated with system maintenance;
•an increase of $6 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives; and
•several individually insignificant items.franchise taxes.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station.service.
Other regulatory charges (credits) - net includes:
•a regulatory creditscharge of $11$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 second quarter 2020 at Entergy Arkansas, to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing.Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the financial statements in the Form 10-Kherein for discussion of the 2019 formula rate plan filing;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 the second quarter 2021 at Entergy Mississippi, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements hereinin 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 changes in decommissioning trust fund activity and a decrease$32 million charge at Entergy Louisiana for the LURC’s 1% beneficial interest in the allowance for equity funds used during construction due to higher construction work in progress in 2020, includingstorm trust established as part of the Montgomery County Power Station project.
Interest expense increased primarily due to: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 issuances by Entergy Louisiana storm trust’s investment of $1.1 billionsecuritization proceeds in affiliated preferred membership interests, partially offset by the liquidation of 0.62% Series mortgage bonds, $300 millionEntergy Louisiana’s investment in affiliated preferred membership interests acquired in connection with previous securitizations of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;
•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;
•the issuance by Entergy Mississippi of $370 million of 3.50% Series mortgage bonds in March 2021; andstorm restoration costs;
•a decrease of $8 million in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project.non-service pension costs; and
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
The•an increase was partially offset by: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 repaymentsissuance 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 5.25%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 $100$70 million of 4.70%4.51% Series mortgage bonds, each in December 2020; and
•the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in MayNovember 2021.
Entergy Wholesale Commodities
Other operation and maintenance expenses decreased from $140 million for the second quarter 2020 to $83 million for the second quarter 2021 to $42 million for the second quarter 2022 primarily due to:
•to a decrease of $35$44 million primarily resulting from the absence of expenses from Indian Point 2, after it was shut down in April 2020, and Indian Point 3, after it was shut down in April 2021;2021, and
•a Palisades, after it was shut down in May 2022. The decrease was partially offset by an increase of $22$5 million in severance and retention expenses. Severance and retention expenses were incurredexpense 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 2020 due to management’s strategy to exitretention costs upon the Entergy Wholesale Commodities merchant power business.
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 of the plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.
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, and Indian Point 2, after it was shut down in April 2020.2021.
Other income decreased primarily due to lower gainslosses on Palisades decommissioning trust fund investments includingin 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 2021.2021, 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.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
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 hereinin 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 103 to the financial statements hereinin the Form 10-K for discussion of the valuation allowance reduction.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
The effective income tax rate was 19.6% for the second quarter 2020.The difference in the effective income tax rate for the second quarter 2020 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.
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 20202021
Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the six months ended June 30, 20212022 to the six months ended June 30, 20202021 showing how much the line itemsitem increased or (decreased) in comparison to the prior period:
| | | |
Utility | | Entergy
Wholesale
Commodities | |
Parent & Other (a) | |
Entergy |
| |
Utility | | Entergy
Wholesale
Commodities | |
Parent & Other (a) | |
Entergy | | | (In Thousands) |
| | (In Thousands) | |
| 2020 Net Income (Loss) Attributable to Entergy Corporation | | $664,685 | | | ($26,344) | | | ($159,094) | | | $479,247 | | |
| 2021 Net Income (Loss) Attributable to Entergy Corporation | | 2021 Net Income (Loss) Attributable to Entergy Corporation | | $682,470 | | | ($237,619) | | | ($116,260) | | | $328,591 | |
| | Operating revenues | Operating revenues | | 962,310 | | | (135,384) | | | 14 | | | 826,940 | | Operating revenues | | 764,425 | | | (158,163) | | | (47) | | | 606,215 | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 387,363 | | | 1,470 | | | (10) | | | 388,823 | | Fuel, fuel-related expenses, and gas purchased for resale | | 179,494 | | | 12,153 | | | 7 | | | 191,654 | |
| Purchased power | Purchased power | | 188,483 | | | 15,037 | | | 10 | | | 203,530 | | Purchased power | | 204,383 | | | 3,770 | | | (7) | | | 208,146 | |
| Other regulatory charges (credits) | | 10,066 | | | — | | | — | | | 10,066 | | |
| Other regulatory charges (credits) - net | | Other regulatory charges (credits) - net | | 755,497 | | | — | | | — | | | 755,497 | |
| Other operation and maintenance | Other operation and maintenance | | 138,801 | | | (89,042) | | | (200) | | | 49,559 | | Other operation and maintenance | | 60,656 | | | (98,570) | | | 6,539 | | | (31,375) | |
| Asset write-offs, impairments, and related charges | | — | | | 333,495 | | | — | | | 333,495 | | |
| Asset write-offs, impairments, and related charges (credits) | | Asset write-offs, impairments, and related charges (credits) | | — | | | (508,686) | | | — | | | (508,686) | |
| Taxes other than income taxes | Taxes other than income taxes | | 5,399 | | | (21,988) | | | 262 | | | (16,327) | | Taxes other than income taxes | | 39,911 | | | (170) | | | 38 | | | 39,779 | |
| Depreciation and amortization | Depreciation and amortization | | 65,956 | | | (33,187) | | | (183) | | | 32,586 | | Depreciation and amortization | | 64,013 | | | (15,392) | | | (954) | | | 47,667 | |
| | Other income (deductions) | Other income (deductions) | | (15,488) | | | 65,285 | | | 10,463 | | | 60,260 | | Other income (deductions) | | (51,580) | | | (106,607) | | | (12,480) | | | (170,667) | |
| Interest expense | Interest expense | | 23,933 | | | (3,914) | | | (1,570) | | | 18,449 | | Interest expense | | 26,062 | | | (5,315) | | | 14,390 | | | 35,137 | |
| Other expenses | Other expenses | | (1,297) | | | (10,633) | | | — | | | (11,930) | | Other expenses | | 1,101 | | | (68,555) | | | — | | | (67,454) | |
| Income taxes | Income taxes | | 110,333 | | | (50,062) | | | (30,666) | | | 29,605 | | Income taxes | | (427,440) | | | 84,224 | | | 2,545 | | | (340,671) | |
| Preferred dividend requirements of subsidiaries and noncontrolling interest | | Preferred dividend requirements of subsidiaries and noncontrolling interest | | (1,563) | | | 1 | | | (96) | | | (1,658) | |
| | 2021 Net Income (Loss) Attributable to Entergy Corporation | | $682,470 | | | ($237,619) | | | ($116,260) | | | $328,591 | | |
| 2022 Net Income (Loss) Attributable to Entergy Corporation | | 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 hereinin the Form 10-K for further discussion of the sale of the Indian Point Energy Center.
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 six months ended June 30, 20212022 to the six months ended June 30, 2020:
| | | | | |
| |
| Amount |
| (In Millions) |
20202021 operating revenues | $4,3085,270 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 682409 | |
| Retail electric price | 187149 | |
| Volume/weather | 107126 | |
| Storm restoration carrying costs | 59 | |
| Return of unprotected excess accumulated deferred income taxes to customers | (14)21 | |
20212022 operating revenues | $5,2706,034 | |
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:
•an increaseincreases in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of May 2021;2021 and January 2022;
•increasesan increase in Entergy Louisiana’s overall formula rate plan revenues, including an interim increase effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station, an increaseincreases in the distribution and transmission recovery mechanism effectivemechanisms, effective September 2020, and an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center;2021;
•increases in Entergy Mississippi’s formula rate plan rates effective in part, with the first billing cycles of April 20202021, July 2021, and April 2021 and the implementation of a vegetation management rider effective with the April 2020 billing cycle;2022;
•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs,rates effective November 2020;2021; and
•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increaseincreases in the transmission cost recovery factor rider effective March 2021 and March 2022, an increase in the distribution cost recovery factor rider effective MarchJanuary 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 1,7673,055 GWh, or 3%5%, in billed electricity usage across all customer classes, including the effect of more favorable weather on residential sales, an increase in industrial usage, and an increase in usage during the unbilled sales period.commercial sales. The increase in industrial usage is primarilywas due to an increase in demand from cogeneration customers, an increase in demand from expansion projects, primarily in the chemicals, transportation, metals, and chemicalspetroleum refining industries, partially offset by decreasedan increase in demand from existing customers, primarily in the chemicals and petroleum refiningpulp and paper industries as a result of prior year temporary plant shutdowns, and operational issues.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,
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
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 the second quarter 2018. In the six months ended June 30, 2021, $542022, $33 million was returned to customers through reductions in operating revenues as compared to $40$54 million in the six months ended June 30, 2020.2021. 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.
BilledTotal electric energy sales for Utility for the six months ended June 30,2021 2022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 16,961 | | | 15,885 | | | 7 | | Residential | 17,946 | | | 17,150 | | | 5 | |
| Commercial | Commercial | 12,504 | | | 12,315 | | | 2 | | Commercial | 13,474 | | | 12,842 | | | 5 | |
| Industrial | Industrial | 24,148 | | | 23,662 | | | 2 | | Industrial | 25,976 | | | 24,378 | | | 7 | |
| Governmental | Governmental | 1,181 | | | 1,165 | | | 1 | | Governmental | 1,226 | | | 1,197 | | | 2 | |
| Total retail | Total retail | 54,794 | | | 53,027 | | | 3 | | Total retail | 58,622 | | | 55,567 | | | 5 | |
| Sales for resale | Sales for resale | 9,016 | | | 6,228 | | | 45 | | Sales for resale | 7,562 | | | 9,016 | | | (16) | |
| Total | Total | 63,810 | | | 59,255 | | | 8 | | Total | 66,184 | | | 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 $532 million for the six months ended June 30, 2020 to $397 million for the six months ended June 30, 2021 to $239 million for the six months ended June 30, 2022 primarily due to the shutdown of Indian Point 2 in April 2020 and the shutdown of Indian Point 3 in April 2021.2021 and Palisades in May 2022.
Following are key performance measures for Entergy Wholesale Commodities for the six months ended June 30,2021 2022 and 2020:2021:
| | | | | | | | | | | |
| 2022 | | 2021 |
| Owned capacity (MW) (a) | 394 | | 1,205 |
| GWh billed | 3,595 | | 7,099 |
| | | |
| Entergy Wholesale Commodities Nuclear Fleet (b) | | | |
| Capacity factor | 93% | | 97% |
| GWh billed | 2,741 | | 6,344 |
| Average energy price ($/MWh) | $48.99 | | $50.70 |
| Average capacity price ($/kW-month) | $0.15 | | $0.26 |
| | | |
| | | |
| | | | | | | | | | | |
| 2021 | | 2020 |
| Owned capacity (MW) (a) | 1,205 | | 2,246 |
| GWh billed | 7,099 | | 11,714 |
| | | |
| Entergy Wholesale Commodities Nuclear Fleet | | | |
| Capacity factor | 97% | | 98% |
| GWh billed | 6,344 | | 10,839 |
| Average energy price ($/MWh) | $50.70 | | $42.37 |
| Average capacity price ($/kW-month) | $0.26 | | $1.58 |
| | | |
| | | |
| | | |
The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the six months ended June 30, 20212022 and 2020.2021.
(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Other Income Statement Items
Utility
Other operation and maintenance expenses increased from $1,155 million for the six months ended June 30, 2020 to $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 $24$18 million in non-nuclearpower 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 during plant outages in 20212022 as compared to 2020prior 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 plants placed in service, including the Lake Charles Power Station,Hardin County Peaking Facility, which began commercial operation in March 2020; the New Orleans Power Station, which began commercial operation in May 2020; the Washington Parish Energy Center,was purchased in November 2020; and the Montgomery County Power Station, which began commercial operation in JanuaryJune 2021;
•an increase of $20$4 million in nuclear generationenergy efficiency expenses primarily due to the timing of recovery from customers and higher nuclear labor costs and a higher scope of work performed in 2021 as compared to 2020;
•an increase of $18 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefitenergy efficiency costs;
•an increase of $17$4 million in distribution operationsloss provisions; and
•several individually insignificant items.
The increase was partially offset by a decrease of $5 million in insurance expenses primarily due to higher distribution reliability costs and higher vegetation maintenance costs;
•lower nuclear insurance refunds of $13 million;received in 2022, partially offset by higher premium costs.
•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $8 million of spent nuclear fuel storage costs previously recorded asTaxes other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;
•an increase of $8 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements in the Form 10-K for further information on the recovery of these costs;
•an increase of $7 millionthan income taxes increased primarily due to contract costsincreases in 2021 related to customer solutionsad valorem taxes resulting from higher assessments, increases in franchise taxes, and sustainability initiatives; and
•an increase of $6 million in information technology costs due to higher contract costs and higher costs associated with system maintenance.employment taxes.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station and the Montgomery County Power Station.service.
Other regulatory charges (credits) - net includes:
•regulatory credits of $22 million, recorded in 2020 at Entergy Arkansas, to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing;
•the reversal in 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 herein and in the Form 10-K for discussion of Entergy Arkansas’sthe 2020 formula rate plan filing;
•$29a 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 first quarter 2020, at Entergy Louisiana, due to a settlement with the IRS related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers.Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 32 to the financial statements in the Form 10-Kherein for further discussion of the settlement and savings obligation;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.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Other income decreased primarily due to:
•regulatory creditschanges in decommissioning trust fund activity, including portfolio rebalancing of $20the decommissioning trust funds in 2022 and 2021; and
•a $32 million recordedcharge at Entergy Louisiana for the LURC’s 1% beneficial interest in the second quarter 2021 at Entergy Mississippi, to reflect the effectsstorm trust established as part of the joint stipulation reachedHurricane 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 2021 formula rate plan filing proceeding. 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 2021 formula rate plan filing.
Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project, partially offset by changes in decommissioning trust fund activity.securitization.
Interest expense increased primarily due to:
•the issuance by Entergy LouisianaArkansas of $350$400 million of 2.90%3.35% Series mortgage bonds in March 2020;2021;
•the issuancesissuance by Entergy LouisianaArkansas of $1.1 billion$200 million of 0.62%4.20% Series mortgage bonds $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;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 $370$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
•a decreasethe 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 the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.November 2021.
The increase was partially offset by:
•by the repaymentsrepayment by Entergy LouisianaArkansas of $200$350 million of 5.25%3.75% Series mortgage bonds in February 2021 and $100 million of 4.70% Series mortgage bonds, each in December 2020; and
•the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.
Entergy Wholesale Commodities
Other operation and maintenance expenses decreased from $271 million for the six months ended June 30, 2020 to $182 million for the six months ended June 30, 2021 to $84 million for the six months ended June 30, 2022 primarily due to:
•to a decrease of $63$87 million resulting from the absence of expenses from Indian Point 2, after it was shut down in April 2020, and Indian Point 3, after it was shut down in April 2021;2021, and
• Palisades, after it was shut down in May 2022, and a decrease of $28$5 million in severance and retention expenses. Severance and retention expenses were incurred in 20212022 and 20202021 due to management’s strategy to exit the Entergy Wholesale Commodities merchant power business.
See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.
Asset write-offs, impairments, and related charges (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
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
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 remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.
Taxes other than income taxes decreased primarily due to lower payroll taxes and lower ad valorem taxes.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Depreciation and amortization expenses decreased primarily due to:
•to the absence of depreciation expense from Indian Point 2, after it was shut down in April 2020, and from Indian Point 3, after it was shut down in April 2021;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 18 to the financial statements hereinin the Form 10-K for discussion of the spent nuclear fuel litigation.
Other income increaseddecreased primarily due to higher gains on decommissioning trust fund investments, partially offset by the absence of earnings from the nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021.2021 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 hereinin 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 hereinin 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 10 to the financial statements herein for discussion of the valuation allowance reduction.
The effective income tax rate was 3.5% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based compensation, 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 3 to the financial statements in the Form 10-K for discussion of the IRS settlement and the income tax deductions for stock-based compensation. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.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 strategy to shut down and sell all remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet. Following are updates to that discussion.
Shutdown and Sale of Indian Point 2 and Indian Point 3
As discussed in the Form 10-K, in April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3 to a Holtec subsidiary for decommissioning the plants.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant nuclear fleet. Following are updates to that discussion.
In November 2019,April 2022, Entergy and Holtec submitted a license transfer applicationNebraska Public Power District signed an agreement to mutually terminate the NRC. The NRC issued an order approvingmanagement support services contract, under which Entergy provided plant operation support services for the application in November 2020, subject to the NRC’s authority to condition, revise, or rescind the approval order based on the resolution of four pending hearing requests. In January 2021 the NRC issued an order denying all four hearing requests challenging the license transfer application. In January 2021, New York State filed a petition for review with the D.C. Circuit asking the court to vacate the NRC’s January 2021 order denying the State’s hearing request, as well as the NRC’s November 2020 order approving the license transfers. In January 2021 the D.C. Circuit issued a scheduling order, setting deadlines for initial procedural filings in March 2021. In March 2021 additional parties also filed petitions for review with the D.C. Circuit seeking review of the same NRC orders. In March 2021 the court consolidated all of the appeals into the same proceeding. Pursuant to an April 2021 settlement among Entergy, Holtec, New York State, and several other parties, discussed below, all petitioners to the D.C. Circuit proceeding withdrew their pending appeals, and the court terminated the consolidated proceeding in June 2021.800 MW Cooper Nuclear Station located near Brownville, Nebraska, effective July 31, 2022.
In November 2019, Entergy and Holtec also submitted a petition to the New York State Public Service Commission (NYPSC) seeking an order from the NYPSC disclaiming jurisdiction or abstaining from review of the transaction or, alternatively, approving the transaction. Closing was also conditioned on obtaining from the New York State Department of Environmental Conservation an agreement related to Holtec’s decommissioning plan as being consistent with applicable standards. In April 2021, Entergy and Holtec filed a joint settlement proposal with the NYPSC that resolved all issues among all parties, including financial assurance, site restoration, financial reporting, continued funding for state and local emergency management and response activities, a memorandum of understanding with local taxing jurisdictions, and the dismissal of the federal appeals described in the preceding paragraph. In May 2021 the NYPSC approved the joint settlement proposal and the transaction.
Indian Point 2 permanently ceased operations on April 30, 2020 and Indian Point 3 permanently ceased operations on April 30, 2021. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. See Note 14 to the financial statements for discussion of the closing of the Indian Point transaction.
Planned Shutdown and Sale of Palisades
As discussed in the Form 10-K, in July 2018, Entergy entered into a purchase and sale agreement to sell 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site, for $1,000 (subject to adjustment for net liabilities and other amounts) to a Holtec subsidiary. Palisades was shut down in May 2022 and defueled in June 2022. The transaction closed in June 2022. The sale will includeincluded 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. The NRC has indicated that it expects to complete its review of the application by January 2022. 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. In March 2021, Entergyapplication, and Holtec filed answers opposingthese petitions and requests for hearing remained pending with the petitions to intervene and hearing requests, andNRC at the petitioners filed replies. In March 2021 an additional party also filed a petition to intervene and request for hearing. Entergy and Holtec filed an answer to the March 2021 petition in April 2021.
Subject to the conditions discussed in the Form 10-K, the transaction is expected to close by the end of 2022. As of June 30, 2021, Entergy’s adjusted net investment in Palisades was $5 million. The primary variables in the ultimate loss or gain that Entergy will incur on the transaction are the valuestime of the nuclear decommissioning trust and the asset retirement obligations at closing the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Costs Associated with Entergy Wholesale Commodities Strategic Transactions
Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. In addition, Entergy Wholesale Commodities incurred impairment charges primarily related to expenditures for capital assets of $2 million for the three months ended June 30, 2021 and $5 million for the six months ended June 30, 2021. These costs were charged to expense as incurred as a result of the impaired value of certain ofPalisades transaction. In July 2022 the Entergy Wholesale Commodities nuclear plants’ long-lived assets due toNRC issued an order granting the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business.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 increasedecrease in the debt to capital ratio for Entergy as of June 30, 20212022 is primarily due to the net issuanceretirement of debt in 2021.2022.
| | | June 30,
2021 | | December 31,
2020 | | June 30,
2022 | | December 31,
2021 |
| Debt to capital | Debt to capital | 69.5 | % | | 68.3 | % | Debt to capital | 69.1 | % | | 69.5 | % |
| Effect of excluding securitization bonds | Effect of excluding securitization bonds | (0.1 | %) | | (0.2 | %) | Effect of excluding securitization bonds | (0.3 | %) | | (0.1 | %) |
| Debt to capital, excluding securitization bonds (a) | Debt to capital, excluding securitization bonds (a) | 69.4 | % | | 68.1 | % | Debt to capital, excluding securitization bonds (a) | 68.8 | % | | 69.4 | % |
| Effect of subtracting cash | Effect of subtracting cash | (0.5 | %) | | (1.7 | %) | Effect of subtracting cash | (0.4 | %) | | (0.3 | %) |
| Net debt to net capital, excluding securitization bonds (a) | Net debt to net capital, excluding securitization bonds (a) | 68.9 | % | | 66.4 | % | Net debt to net capital, excluding securitization bonds (a) | 68.4 | % | | 69.1 | % |
(a)Calculation excludes the Louisiana, New Orleans and Texas securitization bonds, which are non-recourse to Entergy Louisiana, Entergy New Orleans and Entergy Texas, respectively.
As of June 30, 2021, 22.3%2022, 20.6% of the debt outstanding is at the parent company, Entergy Corporation, 77.2%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
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
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 and Subsidiaries
Management's Financial Discussion and Analysis
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.2027. 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, 20212022 was 1.61%1.96% on the drawn portion of the facility. Following is a summaryAs of the borrowingsJune 30, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility as of June 30, 2021:are:
| | | | | | | | | | | | | | | | | | | | |
| Capacity | | Borrowings | | Letters
of Credit | | Capacity
Available |
| (In Millions) |
| $3,500 | | $150 | | $6 | | $3,344 |
| | | | | | | | | | | | | | | | | | | | |
| Capacity | | Borrowings | | Letters
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. One such difference is that it excludes the effects, among other things, of certain impairments related to the Entergy Wholesale Commodities nuclear generation assets. Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy or one of the Registrant SubsidiariesUtility 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 Registrant Subsidiaries’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, 2021,2022, Entergy Corporation had approximately $866 million$1.398 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 20212022 was 0.32%0.91%.
Certain of the Utility operating companies have a total of $72Entergy Louisiana had $290 million and Entergy Mississippi had $33 million in their storm reserve escrow accounts at June 30, 2021.2022.
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
InAs 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. TheInitially, the aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement maycould 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 statementstatements herein for discussion of the forward salessale 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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Management's Financial Discussion and Analysis
(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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Management's Financial Discussion and Analysis
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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Management's Financial Discussion and Analysis
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 20212022 through 2023.2024. Following are updates to that discussion.
Searcy Solar FacilityFollowing are the current annual amounts of Entergy’s planned construction and other capital investments.
As discussed | | | | | | | | | | | | | | | | | | | | |
| Planned construction and capital investments | | 2022 | | 2023 | | 2024 |
| | | (In Millions) |
| Utility: | | | | | | |
| Generation | | $1,080 | | | $1,325 | | | $2,320 | |
| Transmission | | 835 | | | 805 | | | 1,025 | |
| Distribution | | 1,360 | | | 1,520 | | | 1,740 | |
| Utility Support | | 590 | | | 440 | | | 315 | |
| Total | | 3,865 | | | 4,090 | | | 5,400 | |
| Entergy Wholesale Commodities and Other | | 10 | | | — | | | — | |
| 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 Form 10-K,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 April 2020increased duties or tariffs on imported solar panels and has exacerbated previously existing supply chain disruptions, which have negatively affected the APSC issued an order approving Entergy Arkansas’s acquisitiontiming and cost of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the usecompletion of a tax equitythese projects.
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Management's Financial Discussion and Analysis
partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. A decision on the tax equity partnership is requested by September 2021. Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occur by the end of 2021.Walnut Bend Solar
Walnut Bend Solar Facility
In October 2020, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 100 MW Walnut Bend Solar Facility isAs discussed in the public interest. Entergy Arkansas primarily requested cost recovery through the formula rate plan rider. A procedural schedule was established with a paper hearing held in April 2021. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition,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 iswas 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..
Liberty CountyDriver Solar Facility
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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Management's Financial Discussion and Analysis
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 2020,2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquireconstruct, own, and operate the 100Orange County Advanced Power Station, a new 1,215 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisitioncombined-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 facility through a tax equity partnership isestimated 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 public interest.future. In its preliminary order,December 2021 the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s usereferred the proceeding to the State Office of a tax equity partnership is in the public interest.Administrative Hearings. In March 20212022 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 andopposing 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 2021. A2022 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 April 2021. Post-hearingJune 2022 and reply briefing was completedpost-hearing briefs were submitted in May 2021. In July 2021 the presiding administrative law judges issued2022. The initial fixed pricing window closed in July 2022, and Entergy Texas intends to obtain a proposal for decision recommending that thenew fixed pricing option prior to PUCT deny the certification requested in the application. This proposal for decision is subjectapproval and issuance of notice to change based on exceptions filed by the parties. Once it isproceed. A final it will be presented to the PUCT, which may adopt or modify it. A decisionorder by the PUCT is expected in September 2021. Closing, subjectthe 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 occurbe in 2023.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 20212022 meeting, the Board declared a dividend of $0.95$1.01 per share, which is the same quarterly dividend per share that Entergy has paid since the third quarter 2020.2021.
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Management's Financial Discussion and Analysis
Cash Flow Activity
As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions) | | (In Millions) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $1,759 | | | $426 | | Cash and cash equivalents at beginning of period | $443 | | | $1,759 | |
| | Cash flow provided by (used in): | | | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | | | |
| Operating activities | Operating activities | 747 | | | 1,448 | | Operating activities | 816 | | | 747 | |
| Investing activities | Investing activities | (2,826) | | | (2,198) | | Investing activities | (3,224) | | | (2,826) | |
| Financing activities | Financing activities | 1,007 | | | 1,259 | | Financing activities | 2,545 | | | 1,007 | |
| Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | (1,072) | | | 509 | | Net increase (decrease) in cash and cash equivalents | 137 | | | (1,072) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $687 | | | $935 | | Cash and cash equivalents at end of period | $580 | | | $687 | |
Operating Activities
Net cash flow provided by operating activities decreased $701increased $69 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to the following activity:to:
•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;higher collections from Utility customers;
•an increasea decrease of approximately $160 million in storm spending, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;
•an increase of $108$119 million in pension contributions in 20212022 as compared to the same period in 2020.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;
•an increase of $105$119 million in severance and retention payments in 2021 as compared to prior period.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 management’s strategy tothe exit of the Entergy Wholesale Commodities merchant power business;
•a decreasean increase of $45$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 compared to2021. Entergy had income tax refunds in 2022 as a result of $10 million in 2020.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 had income tax refundsWholesale Commodities revenues in 2020 as a result of an overpayment on a prior year state income tax return;2022; and
•a decreasean increase of $18approximately $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 nuclear insurance refunds.
The decrease was partially offset by the timing of collections of receivables from customers and the effect of more favorable weather on billed Utility sales in 2021.storm restoration efforts.
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Management's Financial Discussion and Analysis
Investing Activities
Net cash flow used in investing activities increased $628$398 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•an increase of $777$334 million in distribution construction expenditures primarily duenet payments to storm spendingreserve escrow accounts;
•the initial payment of approximately $105 million in 2021 and increased spending onMay 2022 for the reliability and infrastructurepurchase of the distribution system, partially offsetSunflower Solar facility by lower spending in 2021 on advanced metering infrastructure.the Entergy Mississippi tax equity partnership. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” aboveNote 14 to the financial statements herein for further discussion of storm restoration efforts;the Sunflower Solar facility purchase;
•an increase of $231$101 million in transmissionnuclear construction expenditures primarily due to stormincreased spending on various nuclear projects in 2021, partially offset by a lower scope of work on non-storm projects performed in 2021 as compared to 2020. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts; and2022;
•a decrease of $52 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.
The increase was partially offset by:
•a decrease of $195 million in non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station, Lake Charles Power Station, New Orleans Power Station, and New Orleans Solar Station projects;
•a decrease of $93$55 million in decommissioning trust fund investment activity;
•a decreasean increase of $90$43 million in nuclear constructioninformation technology capital expenditures primarily due to decreased spending on various nuclear projects in 2021;
•a decrease of $46 million in information technology expenditures primarily due to decreasedincreased spending on various technology projects in 2021; and2022;
•a decreasean increase of $40$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.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 decreased $252increased $1,538 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•to proceeds from securitization of $3,164 million received by the storm trust at Entergy Louisiana in 2022 and an increase of $761$958 million in net repaymentsissuances of commercial paper in 20212022 compared to 2020; and
•a decrease of $38 million in treasury stock issuances in 2021 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2020 to satisfy stock option exercises.
2021. The decreaseincrease was partially offset by:
•by long-term debt activity using approximately $442 million of cash in 2022 compared to providing approximately $2,108 million of cash in 2021 compared to providing approximately $1,608 million of cash in 2020; and
•net sales proceeds of $27 million from the issuance of common stock in 2021 under the at the market equity distribution program.2021. See Note 32 to the financial statements herein for a discussion of the equity distribution program.
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.
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Rate, Cost-recovery, and Other Regulation
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Rate, Cost-recovery, and Other Regulation” in the Form 10-K for discussions of rate regulation, federal regulation, and related regulatory proceedings.
State and Local Rate Regulation and Fuel-Cost Recovery
See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding these proceedings.
Federal Regulation
See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding federal regulatory proceedings.
Market and Credit Risk Sensitive Instruments
Commodity Price Risk23
Power Generation
As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” above and in the Form 10-K for a discussion of management’s strategy to shut down and sell all remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet. As of June 30, 2021, Palisades is the only remaining plant in the Entergy Wholesale Commodities merchant nuclear fleet. Almost all of the Palisades output is sold under a power purchase agreement that is scheduled to expire in 2022. Following is a summary of Entergy Wholesale Commodities’ current forward capacity and generation contracts as well as total revenue projections based on market prices as of June 30, 2021 (2021 represents the remainder of the year):
Entergy Wholesale Commodities Nuclear Portfolio
| | | | | | | | | | | | | | |
| | 2021 | | 2022 |
| Energy | | | | |
| Percent of planned generation under contract (a): | | | | |
| Unit-contingent (b) | | 98% | | 99% |
| Planned generation (TWh) (c) (d) | | 3.4 | | 2.8 |
| Average revenue per MWh on contracted volumes: | | | | |
| Expected based on market prices as of June 30, 2021 | | $62.1 | | $47.1 |
| | | | |
| Capacity | | | | |
| Percent of capacity sold forward (e): | | | | |
| Bundled capacity and energy contracts (f) | | 98% | | 98% |
| Planned net MW in operation (average) (d) | | 803 | | 338 |
| Total Energy and Capacity Revenues (g) | | | | |
| Expected sold and market total revenue per MWh | | $61.5 | | $46.9 |
| Sensitivity: -/+ $10 per MWh market price change | | $61.4-$61.7 | | $46.7-$47.0 |
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
Market and Credit Risk Sensitive Instruments
(a)Percent of planned generation output sold under unit-contingent contracts.
(b)Transaction under which power is supplied from a specific generation asset; if the asset is not operating, the seller is generally not liable to the buyer for any damages. Certain unit-contingent sales include a guarantee of availability. Availability guarantees provide for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.
(c)Amount of output expected to be generated by Entergy Wholesale Commodities nuclear resources considering plant operating characteristics.
(d)Assumes the planned shutdown of Palisades on May 31, 2022. For a discussion regarding the planned shutdown of the Palisades plant, see “Entergy Wholesale Commodities Exit from the Merchant Power BusinessPortfolio” above.
(e)Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.
(f)A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.
(g)Excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.
Some of the agreements to sell the power produced by Entergy Wholesale Commodities’ power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations under the agreements. The Entergy subsidiary is required to provide credit support based upon the difference between the current market prices and contracted power prices in the regions where Entergy Wholesale Commodities sells power. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. Cash and letters of credit are also acceptable forms of credit support. At June 30, 2021,2022, based on power prices at that time, Entergy had liquidity exposure of $41$24 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $6$12 million of posted cash collateral. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of June 30, 2021, Entergy would have been required to provide approximately $30 million of additional cash or letters of credit under some of the agreements. As of June 30, 2021, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by an insignificant amount for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.
As of June 30, 2021, substantially all of the credit exposure associated with the planned energy output under contract for the Palisades plant through 2022 is with counterparties or their guarantors that have public investment grade credit ratings.
Nuclear Matters
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. Following are updates to the discussion in the Form 10-K.
NRC Reactor Oversight Process
As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
associated costs. Nuclear generating plants owned and operated by Entergy’s Utility and Entergy Wholesale Commodities businesses are currently in Column 1, except for Grand Gulf, which is in Column 3.
In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.
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
Entergy Corporation and Subsidiaries
Management's Financial Discussion and Analysis
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.
| | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2021 and 2020 |
| (Unaudited) |
| | | | | |
| Three Months Ended | | Six Months Ended |
| 2021 | | 2020 | | 2021 | | 2020 |
| (In Thousands, Except Share Data) |
| OPERATING REVENUES | | | | | | | |
| Electric | $2,641,375 | | | $2,190,557 | | | $5,179,794 | | | $4,241,196 | |
| Natural gas | 31,998 | | | 22,495 | | | 90,166 | | | 66,471 | |
| Competitive businesses | 148,697 | | | 199,736 | | | 396,947 | | | 532,300 | |
| TOTAL | 2,822,070 | | | 2,412,788 | | | 5,666,907 | | | 4,839,967 | |
| | | | | | | |
| OPERATING EXPENSES | | | | | | | |
| Operation and Maintenance: | | | | | | | |
| Fuel, fuel-related expenses, and gas purchased for resale | 626,064 | | | 341,005 | | | 1,127,231 | | | 738,408 | |
| Purchased power | 252,371 | | | 211,961 | | | 632,105 | | | 428,575 | |
| Nuclear refueling outage expenses | 43,700 | | | 44,894 | | | 87,438 | | | 95,112 | |
| Other operation and maintenance | 781,118 | | | 736,261 | | | 1,487,904 | | | 1,438,345 | |
| Asset write-offs, impairments, and related charges | 342,092 | | | 6,775 | | | 345,365 | | | 11,870 | |
| Decommissioning | 86,199 | | | 95,413 | | | 184,841 | | | 189,097 | |
| Taxes other than income taxes | 155,911 | | | 158,646 | | | 312,613 | | | 328,940 | |
| Depreciation and amortization | 421,545 | | | 403,769 | | | 836,064 | | | 803,478 | |
| Other regulatory charges (credits) - net | (55,138) | | | (25,247) | | | (22,859) | | | (32,925) | |
| TOTAL | 2,653,862 | | | 1,973,477 | | | 4,990,702 | | | 4,000,900 | |
| | | | | | | |
| OPERATING INCOME | 168,208 | | | 439,311 | | | 676,205 | | | 839,067 | |
| | | | | | | |
| OTHER INCOME | | | | | | | |
| Allowance for equity funds used during construction | 16,873 | | | 28,370 | | | 31,449 | | | 64,324 | |
| Interest and investment income | 71,329 | | | 284,823 | | | 214,645 | | | 67,969 | |
| Miscellaneous - net | (62,844) | | | (93,620) | | | (123,773) | | | (70,232) | |
| TOTAL | 25,358 | | | 219,573 | | | 122,321 | | | 62,061 | |
| | | | | | | |
| INTEREST EXPENSE | | | | | | | |
| Interest expense | 220,340 | | | 216,799 | | | 426,226 | | | 422,388 | |
| Allowance for borrowed funds used during construction | (6,964) | | | (12,143) | | | (12,976) | | | (27,587) | |
| TOTAL | 213,376 | | | 204,656 | | | 413,250 | | | 394,801 | |
| | | | | | | |
| INCOME (LOSS) BEFORE INCOME TAXES | (19,810) | | | 454,228 | | | 385,276 | | | 506,327 | |
| | | | | | | |
| Income taxes | (18,416) | | | 89,115 | | | 47,526 | | | 17,921 | |
| | | | | | | |
| CONSOLIDATED NET INCOME (LOSS) | (1,394) | | | 365,113 | | | 337,750 | | | 488,406 | |
| | | | | | | |
| Preferred dividend requirements of subsidiaries | 4,580 | | | 4,580 | | | 9,159 | | | 9,159 | |
| | | | | | | |
| NET INCOME (LOSS) ATTRIBUTABLE TO ENTERGY CORPORATION | ($5,974) | | | $360,533 | | | $328,591 | | | $479,247 | |
| | | | | | | |
| Earnings (loss) per average common share: | | | | | | | |
| Basic | ($0.03) | | | $1.80 | | | $1.64 | | | $2.40 | |
| Diluted | ($0.03) | | | $1.79 | | | $1.63 | | | $2.39 | |
| | | | | | | |
| Basic average number of common shares outstanding | 200,775,395 | | | 200,178,010 | | | 200,651,162 | | | 199,984,013 | |
| Diluted average number of common shares outstanding | 200,775,395 | | | 200,886,749 | | | 201,352,830 | | | 200,891,134 | |
| | | | | | | |
| See Notes to Financial Statements. | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME |
| For the Three and Six Months Ended June 30, 2021 and 2020 |
| (Unaudited) |
| | | | | | | |
| Three Months Ended | | Six Months Ended |
| 2021 | | 2020 | | 2021 | | 2020 |
| | | | | | | |
| (In Thousands) |
| | | | | | | |
| Net Income (Loss) | ($1,394) | | | $365,113 | | | $337,750 | | | $488,406 | |
| | | | | | | |
| Other comprehensive income (loss) | | | | | | | |
| Cash flow hedges net unrealized loss (net of tax benefit of $66, $6,760, $7,935, and $12,537) | (222) | | | (25,406) | | | (29,802) | | | (47,116) | |
| Pension and other postretirement liabilities (net of tax expense of $6,231, $4,713, $12,545, and $19,789) | 22,098 | | | 17,224 | | | 45,065 | | | 71,123 | |
| Net unrealized investment gain (loss) (net of tax expense (benefit) of ($27), $10,812, ($25,608), and $19,555) | (108) | | | 18,565 | | | (44,795) | | | 34,309 | |
| Other comprehensive income (loss) | 21,768 | | | 10,383 | | | (29,532) | | | 58,316 | |
| | | | | | | |
| Comprehensive Income | 20,374 | | | 375,496 | | | 308,218 | | | 546,722 | |
| Preferred dividend requirements of subsidiaries | 4,580 | | | 4,580 | | | 9,159 | | | 9,159 | |
| Comprehensive Income Attributable to Entergy Corporation | $15,794 | | | $370,916 | | | $299,059 | | | $537,563 | |
| | | | | | | |
| See Notes to Financial Statements. | | | | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 |
| (Unaudited) |
| | 2021 | | 2020 |
| | (In Thousands) |
| OPERATING ACTIVITIES | | | | |
| Consolidated net income | | $337,750 | | | $488,406 | |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | | | | |
| Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 1,150,294 | | | 1,131,212 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | | 115,274 | | | 68,332 | |
| Asset write-offs, impairments, and related charges | | 345,339 | | | 11,735 | |
| | | | |
| Changes in working capital: | | | | |
| Receivables | | (154,277) | | | (30,990) | |
| Fuel inventory | | 16,718 | | | (19,897) | |
| Accounts payable | | (131,414) | | | (39,054) | |
| Taxes accrued | | (69,711) | | | 44,469 | |
| Interest accrued | | (162) | | | 4,188 | |
| Deferred fuel costs | | (286,116) | | | 33,298 | |
| Other working capital accounts | | (86,774) | | | (63,943) | |
| Changes in provisions for estimated losses | | (54,278) | | | (37,968) | |
| Changes in other regulatory assets | | 93,776 | | | 74,610 | |
| Changes in other regulatory liabilities | | 170,932 | | | (164,158) | |
| Changes in pension and other postretirement liabilities | | (259,593) | | | (177,224) | |
| Other | | (441,211) | | | 125,291 | |
| Net cash flow provided by operating activities | | 746,547 | | | 1,448,307 | |
| | | | |
| INVESTING ACTIVITIES | | | | |
| Construction/capital expenditures | | (2,883,376) | | | (2,185,294) | |
| Allowance for equity funds used during construction | | 31,449 | | | 64,324 | |
| Nuclear fuel purchases | | (73,858) | | | (113,592) | |
| Payment for purchase of plant or assets | | (36,534) | | | (24,633) | |
| Net proceeds from sale of assets | | 22,421 | | | 0 | |
| | | | |
| Changes in securitization account | | 9,685 | | | 12,525 | |
| Payments to storm reserve escrow account | | (17) | | | (1,965) | |
| Receipts from storm reserve escrow account | | 44,205 | | | 40,589 | |
| Decrease in other investments | | 10,753 | | | 2,262 | |
| Litigation proceeds for reimbursement of spent nuclear fuel storage costs | | 15,735 | | | 67,252 | |
| Proceeds from nuclear decommissioning trust fund sales | | 3,837,482 | | | 1,249,548 | |
| Investment in nuclear decommissioning trust funds | | (3,804,170) | | | (1,309,209) | |
| Net cash flow used in investing activities | | (2,826,225) | | | (2,198,193) | |
| | | | |
| See Notes to Financial Statements. | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 |
| (Unaudited) |
| | 2021 | | 2020 |
| | (In Thousands) |
| FINANCING ACTIVITIES | | | | |
| Proceeds from the issuance of: | | | | |
| Long-term debt | | 5,008,330 | | | 5,201,010 | |
| | | | |
| Treasury stock | | 4,039 | | | 41,753 | |
| Common stock | | 26,817 | | | 0 | |
| Retirement of long-term debt | | (2,900,566) | | | (3,592,919) | |
| | | | |
| | | | |
| Changes in credit borrowings and commercial paper - net | | (761,244) | | | (508) | |
| Other | | 20,467 | | | (8,448) | |
| Dividends paid: | | | | |
| Common stock | | (381,224) | | | (371,914) | |
| Preferred stock | | (9,159) | | | (9,342) | |
| Net cash flow provided by financing activities | | 1,007,460 | | | 1,259,632 | |
| | | | |
| | | | |
| | | | |
| Net increase (decrease) in cash and cash equivalents | | (1,072,218) | | | 509,746 | |
| | | | |
| Cash and cash equivalents at beginning of period | | 1,759,099 | | | 425,722 | |
| | | | |
| Cash and cash equivalents at end of period | | $686,881 | | | $935,468 | |
| | | | |
| SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | | | |
| Cash paid (received) during the period for: | | | | |
| Interest - net of amount capitalized | | $428,301 | | | $405,248 | |
| Income taxes | | $27,488 | | | ($10,007) | |
| | | | |
| See Notes to Financial Statements. | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS |
| ASSETS |
| June 30, 2021 and December 31, 2020 |
| (Unaudited) |
| | 2021 | | 2020 |
| | (In Thousands) |
| CURRENT ASSETS | | | | |
| Cash and cash equivalents: | | | | |
| Cash | | $157,265 | | | $128,851 | |
| Temporary cash investments | | 529,616 | | | 1,630,248 | |
| Total cash and cash equivalents | | 686,881 | | | 1,759,099 | |
| Accounts receivable: | | | | |
| Customer | | 877,221 | | | 833,478 | |
| Allowance for doubtful accounts | | (109,189) | | | (117,794) | |
| Other | | 158,262 | | | 135,208 | |
| Accrued unbilled revenues | | 513,710 | | | 434,835 | |
| Total accounts receivable | | 1,440,004 | | | 1,285,727 | |
| Deferred fuel costs | | 152,230 | | | 4,380 | |
| Fuel inventory - at average cost | | 156,216 | | | 172,934 | |
| Materials and supplies - at average cost | | 990,088 | | | 962,185 | |
| Deferred nuclear refueling outage costs | | 173,365 | | | 179,150 | |
| Prepayments and other | | 195,922 | | | 196,424 | |
| TOTAL | | 3,794,706 | | | 4,559,899 | |
| | | | |
| OTHER PROPERTY AND INVESTMENTS | | | | |
| | | | |
| Decommissioning trust funds | | 5,238,727 | | | 7,253,215 | |
| Non-utility property - at cost (less accumulated depreciation) | | 353,423 | | | 343,328 | |
| Other | | 156,766 | | | 214,222 | |
| TOTAL | | 5,748,916 | | | 7,810,765 | |
| | | | |
| PROPERTY, PLANT, AND EQUIPMENT | | | | |
| Electric | | 61,064,428 | | | 59,696,443 | |
| | | | |
| Natural gas | | 631,471 | | | 610,768 | |
| Construction work in progress | | 1,383,758 | | | 2,012,030 | |
| Nuclear fuel | | 549,166 | | | 601,281 | |
| TOTAL PROPERTY, PLANT, AND EQUIPMENT | | 63,628,823 | | | 62,920,522 | |
| Less - accumulated depreciation and amortization | | 24,197,413 | | | 24,067,745 | |
| PROPERTY, PLANT, AND EQUIPMENT - NET | | 39,431,410 | | | 38,852,777 | |
| | | | |
| DEFERRED DEBITS AND OTHER ASSETS | | | | |
| Regulatory assets: | | | | |
| | | | |
| Other regulatory assets (includes securitization property of $83,195 as of June 30, 2021 and $119,238 as of December 31, 2020) | | 5,982,773 | | | 6,076,549 | |
| Deferred fuel costs | | 240,688 | | | 240,422 | |
| Goodwill | | 377,172 | | | 377,172 | |
| Accumulated deferred income taxes | | 60,749 | | | 76,289 | |
| Other | | 312,869 | | | 245,339 | |
| TOTAL | | 6,974,251 | | | 7,015,771 | |
| | | | |
| TOTAL ASSETS | | $55,949,283 | | | $58,239,212 | |
| | | | |
| See Notes to Financial Statements. | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF OPERATIONS |
| For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | | | | |
| Three Months Ended | | Six Months Ended |
| 2022 | | 2021 | | 2022 | | 2021 |
| (In Thousands, Except Share Data) |
| OPERATING REVENUES | | | | | | | |
| Electric | $3,258,255 | | | $2,641,375 | | | $5,914,031 | | | $5,179,794 | |
| Natural gas | 48,008 | | | 31,998 | | | 120,369 | | | 90,166 | |
| Competitive businesses | 88,933 | | | 148,697 | | | 238,722 | | | 396,947 | |
| TOTAL | 3,395,196 | | | 2,822,070 | | | 6,273,122 | | | 5,666,907 | |
| | | | | | | |
| OPERATING EXPENSES | | | | | | | |
| Operation and Maintenance: | | | | | | | |
| Fuel, fuel-related expenses, and gas purchased for resale | 651,946 | | | 626,064 | | | 1,318,885 | | | 1,127,231 | |
| Purchased power | 570,627 | | | 252,371 | | | 840,251 | | | 632,105 | |
| Nuclear refueling outage expenses | 36,917 | | | 43,700 | | | 79,918 | | | 87,438 | |
| Other operation and maintenance | 777,715 | | | 781,118 | | | 1,456,529 | | | 1,487,904 | |
| Asset write-offs, impairments, and related charges (credits) | (164,066) | | | 342,092 | | | (163,321) | | | 345,365 | |
| Decommissioning | 62,859 | | | 86,199 | | | 124,907 | | | 184,841 | |
| Taxes other than income taxes | 172,244 | | | 155,911 | | | 352,392 | | | 312,613 | |
| Depreciation and amortization | 444,759 | | | 421,545 | | | 883,731 | | | 836,064 | |
| Other regulatory charges (credits) - net | 761,063 | | | (55,138) | | | 732,638 | | | (22,859) | |
| TOTAL | 3,314,064 | | | 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 construction | 13,568 | | | 16,873 | | | 29,440 | | | 31,449 | |
| Interest and investment income (loss) | (99,049) | | | 71,329 | | | (120,968) | | | 214,645 | |
| Miscellaneous - net | 35,578 | | | (62,844) | | | 43,182 | | | (123,773) | |
| TOTAL | (49,903) | | | 25,358 | | | (48,346) | | | 122,321 | |
| | | | | | | |
| INTEREST EXPENSE | | | | | | | |
| Interest expense | 231,613 | | | 220,340 | | | 459,235 | | | 426,226 | |
| Allowance for borrowed funds used during construction | (4,752) | | | (6,964) | | | (10,848) | | | (12,976) | |
| TOTAL | 226,861 | | | 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 interest | 4,308 | | | 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 outstanding | 203,383,199 | | | 200,775,395 | | | 203,164,628 | | | 200,651,162 | |
| Diluted average number of common shares outstanding | 204,712,242 | | | 200,775,395 | | | 204,291,597 | | | 201,352,830 | |
| | | | | | | |
| See Notes to Financial Statements. | | | | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 |
| (Unaudited) |
| | 2021 | | 2020 |
| | (In Thousands) |
| CURRENT LIABILITIES | | | | |
| Currently maturing long-term debt | | $285,324 | | | $1,164,015 | |
| Notes payable and commercial paper | | 866,245 | | | 1,627,489 | |
| Accounts payable | | 1,348,734 | | | 2,739,437 | |
| Customer deposits | | 390,306 | | | 401,512 | |
| Taxes accrued | | 371,300 | | | 441,011 | |
| Interest accrued | | 201,629 | | | 201,791 | |
| Deferred fuel costs | | 15,111 | | | 153,113 | |
| | | | |
| Pension and other postretirement liabilities | | 67,963 | | | 61,815 | |
| Current portion of unprotected excess accumulated deferred income taxes | | 64,288 | | | 63,683 | |
| Other | | 193,640 | | | 206,640 | |
| TOTAL | | 3,804,540 | | | 7,060,506 | |
| | | | |
| NON-CURRENT LIABILITIES | | | | |
| Accumulated deferred income taxes and taxes accrued | | 4,375,535 | | | 4,361,772 | |
| Accumulated deferred investment tax credits | | 215,828 | | | 212,494 | |
| | | | |
| Regulatory liability for income taxes-net | | 1,435,112 | | | 1,521,757 | |
| Other regulatory liabilities | | 2,580,823 | | | 2,323,851 | |
| Decommissioning and asset retirement cost liabilities | | 4,635,300 | | | 6,469,452 | |
| Accumulated provisions | | 188,557 | | | 242,835 | |
| Pension and other postretirement liabilities | | 2,587,272 | | | 2,853,013 | |
| Long-term debt (includes securitization bonds of $113,572 as of June 30, 2021 and $174,635 as of December 31, 2020) | | 24,211,966 | | | 21,205,761 | |
| Other | | 771,993 | | | 807,219 | |
| TOTAL | | 41,002,386 | | | 39,998,154 | |
| | | | |
| Commitments and Contingencies | | | | |
| | | | |
| Subsidiaries' preferred stock without sinking fund | | 219,410 | | | 219,410 | |
| | | | |
| EQUITY | | | | |
| Preferred stock, no par value, authorized 1,000,000 shares in 2021 and 0 shares in 2020; issued shares in 2021 and 2020 - NaN | | 0 | | | 0 | |
| Common stock, $.01 par value, authorized 499,000,000 shares; issued 270,300,648 shares in 2021 and 270,035,180 shares in 2020 | | 2,703 | | | 2,700 | |
| Paid-in capital | | 6,561,676 | | | 6,549,923 | |
| Retained earnings | | 9,844,549 | | | 9,897,182 | |
| Accumulated other comprehensive loss | | (478,739) | | | (449,207) | |
| Less - treasury stock, at cost (69,347,286 shares in 2021 and 69,790,346 shares in 2020) | | 5,042,242 | | | 5,074,456 | |
| Total common shareholders' equity | | 10,887,947 | | | 10,926,142 | |
| Subsidiaries' preferred stock without sinking fund | | 35,000 | | | 35,000 | |
| TOTAL | | 10,922,947 | | | 10,961,142 | |
| | | | |
| TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY | | $55,949,283 | | | $58,239,212 | |
| | | | |
| See Notes to Financial Statements. | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME |
| For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | | | | | | |
| Three Months Ended | | Six Months Ended |
| 2022 | | 2021 | | 2022 | | 2021 |
| | | | | | | |
| (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 interest | 4,308 | | | 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. | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENT OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2021 |
| (Unaudited) |
| | | | | |
| | | Common Shareholders’ Equity | | |
| Subsidiaries’ Preferred Stock | | Common
Stock | | Treasury
Stock | | Paid-in
Capital | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total |
| (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 | | | 0 | | | 0 | | | 0 | | | 334,565 | | | 0 | | | 339,145 | |
| Other comprehensive loss | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | (51,300) | | | (51,300) | |
| Common stock issuances related to stock plans | 0 | | | 0 | | | 28,235 | | | (29,871) | | | 0 | | | 0 | | | (1,636) | |
| Common stock dividends declared | 0 | | | 0 | | | 0 | | | 0 | | | (190,595) | | | 0 | | | (190,595) | |
| Preferred dividend requirements of subsidiaries (a) | (4,580) | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | (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 | | | 0 | | | 0 | | | 0 | | | (5,974) | | | 0 | | | (1,394) | |
| Other comprehensive income | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | 21,768 | | | 21,768 | |
| Common stock issuances and sales under the at the market equity distribution program | 0 | | | 3 | | | 0 | | | 28,213 | | | 0 | | | 0 | | | 28,216 | |
| Common stock issuance costs | 0 | | | 0 | | | 0 | | | (1,399) | | | 0 | | | 0 | | | (1,399) | |
| Common stock issuances related to stock plans | 0 | | | 0 | | | 3,979 | | | 14,810 | | | 0 | | | 0 | | | 18,789 | |
| Common stock dividends declared | 0 | | | 0 | | | 0 | | | 0 | | | (190,629) | | | 0 | | | (190,629) | |
| Preferred dividend requirements of subsidiaries (a) | (4,580) | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | (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 (loss) and preferred dividend requirements of subsidiaries for first quarter 2021 and second quarter 2021 each includes $4.1 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity. |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | 2022 | | 2021 |
| | (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 amortization | | 1,113,954 | | | 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 inventory | | 16,381 | | | 16,718 | |
| Accounts payable | | 42,915 | | | (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 losses | | 295,987 | | | (54,278) | |
| Changes in other regulatory assets | | 724,227 | | | 93,776 | |
| Changes in other regulatory liabilities | | 15,788 | | | 170,932 | |
| Effect of securitization on regulatory asset | | (1,036,955) | | | — | |
| | | | |
| Changes in pension and other postretirement liabilities | | (167,682) | | | (259,593) | |
| Other | | 846,170 | | | (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 construction | | 29,440 | | | 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 agreement | | 9,829 | | | — | |
| Changes in securitization account | | 337 | | | 9,685 | |
| Payments to storm reserve escrow account | | (1,290,314) | | | (17) | |
| Receipts from storm reserve escrow account | | 1,000,218 | | | 44,205 | |
| Decrease (increase) in other investments | | (36,057) | | | 10,753 | |
| Litigation proceeds for reimbursement of spent nuclear fuel storage costs | | 32,367 | | | 15,735 | |
| Proceeds from nuclear decommissioning trust fund sales | | 1,099,503 | | | 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. | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENT OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2020 |
| (Unaudited) |
| | | | | | | | | | | | | |
| | | Common Shareholders’ Equity | | |
| Subsidiaries' Preferred Stock | | Common
Stock | | Treasury
Stock | | Paid-in
Capital | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total |
| (In Thousands) |
| Balance at December 31, 2019 | $35,000 | | | $2,700 | | | ($5,154,150) | | | $6,564,436 | | | $9,257,609 | | | ($446,920) | | | $10,258,675 | |
| Implementation of accounting standards | 0 | | | 0 | | | 0 | | | 0 | | | (419) | | | 0 | | | (419) | |
| Balance at January 1, 2020 | 35,000 | | | 2,700 | | | (5,154,150) | | | 6,564,436 | | | 9,257,190 | | | (446,920) | | | 10,258,256 | |
| | | | | | | | | | | | | |
| Consolidated net income (a) | 4,580 | | | 0 | | | 0 | | | 0 | | | 118,714 | | | 0 | | | 123,294 | |
| Other comprehensive income | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | 47,933 | | | 47,933 | |
| Common stock issuances related to stock plans | 0 | | | 0 | | | 73,580 | | | (53,753) | | | 0 | | | 0 | | | 19,827 | |
| Common stock dividends declared | 0 | | | 0 | | | 0 | | | 0 | | | (185,763) | | | 0 | | | (185,763) | |
| Preferred dividend requirements of subsidiaries (a) | (4,580) | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | (4,580) | |
| Balance at March 31, 2020 | $35,000 | | | $2,700 | | | ($5,080,570) | | | $6,510,683 | | | $9,190,141 | | | ($398,987) | | | $10,258,967 | |
| | | | | | | | | | | | | |
| Consolidated net income (a) | 4,580 | | | 0 | | | 0 | | | 0 | | | 360,533 | | | 0 | | | 365,113 | |
| Other comprehensive income | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | 10,383 | | | 10,383 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Common stock issuances related to stock plans | 0 | | | 0 | | | 3,609 | | | 13,647 | | | 0 | | | 0 | | | 17,256 | |
| Common stock dividends declared | 0 | | | 0 | | | 0 | | | 0 | | | (186,151) | | | 0 | | | (186,151) | |
| Preferred dividend requirements of subsidiaries (a) | (4,580) | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | (4,580) | |
| Balance at June 30, 2020 | $35,000 | | | $2,700 | | | ($5,076,961) | | | $6,524,330 | | | $9,364,523 | | | ($388,604) | | | $10,460,988 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | |
| | | | | | | | | | | | | |
| (a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2020 and second quarter 2020 each includes $4.1 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity. |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | 2022 | | 2021 |
| | (In Thousands) |
| FINANCING ACTIVITIES | | | | |
| Proceeds from the issuance of: | | | | |
| Long-term debt | | 3,851,061 | | | 5,008,330 | |
| | | | |
| Treasury stock | | 26,952 | | | 4,039 | |
| Common stock | | — | | | 26,817 | |
| Retirement of long-term debt | | (4,293,423) | | | (2,900,566) | |
| | | | |
| | | | |
| Changes in credit borrowings and commercial paper - net | | 196,694 | | | (761,244) | |
| Capital contribution from noncontrolling interest | | 9,595 | | | — | |
| Proceeds from trust related to securitization | | 3,163,572 | | | — | |
| Other | | 10,523 | | | 20,467 | |
| Dividends paid: | | | | |
| Common stock | | (410,466) | | | (381,224) | |
| Preferred stock | | (9,159) | | | (9,159) | |
| Net cash flow provided by financing activities | | 2,545,349 | | | 1,007,460 | |
| | | | |
| | | | |
| | | | |
| Net increase (decrease) in cash and cash equivalents | | 137,330 | | | (1,072,218) | |
| | | | |
| Cash and cash equivalents at beginning of period | | 442,559 | | | 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. | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS |
| ASSETS |
| June 30, 2022 and December 31, 2021 |
| (Unaudited) |
| | 2022 | | 2021 |
| | (In Thousands) |
| CURRENT ASSETS | | | | |
| Cash and cash equivalents: | | | | |
| Cash | | $66,265 | | | $44,944 | |
| Temporary cash investments | | 513,624 | | | 397,615 | |
| Total cash and cash equivalents | | 579,889 | | | 442,559 | |
| Accounts receivable: | | | | |
| Customer | | 804,552 | | | 786,866 | |
| Allowance for doubtful accounts | | (25,587) | | | (68,608) | |
| Other | | 238,496 | | | 231,843 | |
| Accrued unbilled revenues | | 545,027 | | | 420,255 | |
| Total accounts receivable | | 1,562,488 | | | 1,370,356 | |
| Deferred fuel costs | | 983,935 | | | 324,394 | |
| Fuel inventory - at average cost | | 138,194 | | | 154,575 | |
| Materials and supplies - at average cost | | 1,094,564 | | | 1,041,515 | |
| Deferred nuclear refueling outage costs | | 186,682 | | | 133,422 | |
| Prepayments and other | | 249,659 | | | 156,774 | |
| TOTAL | | 4,795,411 | | | 3,623,595 | |
| | | | |
| OTHER PROPERTY AND INVESTMENTS | | | | |
| | | | |
| Decommissioning trust funds | | 4,090,109 | | | 5,514,016 | |
| Non-utility property - at cost (less accumulated depreciation) | | 358,609 | | | 357,576 | |
| Other | | 445,181 | | | 159,455 | |
| TOTAL | | 4,893,899 | | | 6,031,047 | |
| | | | |
| PROPERTY, PLANT, AND EQUIPMENT | | | | |
| Electric | | 63,209,561 | | | 64,263,250 | |
| | | | |
| Natural gas | | 672,282 | | | 658,989 | |
| Construction work in progress | | 1,827,581 | | | 1,511,966 | |
| Nuclear fuel | | 518,120 | | | 577,006 | |
| TOTAL PROPERTY, PLANT, AND EQUIPMENT | | 66,227,544 | | | 67,011,211 | |
| Less - accumulated depreciation and amortization | | 25,013,847 | | | 24,767,051 | |
| PROPERTY, PLANT, AND EQUIPMENT - NET | | 41,213,697 | | | 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 costs | | 241,052 | | | 240,953 | |
| Goodwill | | 377,172 | | | 377,172 | |
| Accumulated deferred income taxes | | 87,600 | | | 54,186 | |
| Other | | 329,719 | | | 269,873 | |
| TOTAL | | 6,924,572 | | | 7,555,440 | |
| | | | |
| TOTAL ASSETS | | $57,827,579 | | | $59,454,242 | |
| | | | |
| See Notes to Financial Statements. | | | | |
| | | | | | | | | | | | | | |
| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY |
| June 30, 2022 and December 31, 2021 |
| (Unaudited) |
| | 2022 | | 2021 |
| | (In Thousands) |
| CURRENT LIABILITIES | | | | |
| Currently maturing long-term debt | | $909,030 | | | $1,039,329 | |
| Notes payable and commercial paper | | 1,397,871 | | | 1,201,177 | |
| Accounts payable | | 1,935,286 | | | 2,610,132 | |
| Customer deposits | | 410,307 | | | 395,184 | |
| Taxes accrued | | 419,408 | | | 419,828 | |
| Interest accrued | | 179,204 | | | 191,151 | |
| Deferred fuel costs | | — | | | 7,607 | |
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| Pension and other postretirement liabilities | | 61,911 | | | 68,336 | |
| Current portion of unprotected excess accumulated deferred income taxes | | 18,935 | | | 53,385 | |
| Other | | 209,663 | | | 204,613 | |
| TOTAL | | 5,541,615 | | | 6,190,742 | |
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| NON-CURRENT LIABILITIES | | | | |
| Accumulated deferred income taxes and taxes accrued | | 4,479,428 | | | 4,706,797 | |
| Accumulated deferred investment tax credits | | 207,868 | | | 211,975 | |
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| Regulatory liability for income taxes - net | | 1,216,339 | | | 1,255,692 | |
| Other regulatory liabilities | | 2,733,436 | | | 2,643,845 | |
| Decommissioning and asset retirement cost liabilities | | 4,173,137 | | | 4,757,084 | |
| Accumulated provisions | | 453,109 | | | 157,122 | |
| Pension and other postretirement liabilities | | 1,788,068 | | | 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 | |
| Other | | 652,702 | | | 815,284 | |
| TOTAL | | 40,247,983 | | | 41,338,696 | |
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| Commitments and Contingencies | | | | |
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| Subsidiaries' preferred stock without sinking fund | | 219,410 | | | 219,410 | |
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| 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 capital | | 6,750,368 | | | 6,766,239 | |
| Retained earnings | | 10,266,189 | | | 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' equity | | 11,711,079 | | | 11,637,284 | |
| Subsidiaries' preferred stock without sinking fund and noncontrolling interest | | 107,492 | | | 68,110 | |
| TOTAL | | 11,818,571 | | | 11,705,394 | |
| | | | |
| TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY | | $57,827,579 | | | $59,454,242 | |
| | | | |
| See Notes to Financial Statements. | | | | |
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| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2022 |
| (Unaudited) |
| | | | | |
| | | Common Shareholders’ Equity | | |
| Subsidiaries’ Preferred Stock and Noncontrolling Interest | | Common
Stock | | Treasury
Stock | | Paid-in
Capital | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total |
| (In Thousands) |
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| Balance at December 31, 2021 | $68,110 | | | $2,720 | | | ($5,039,699) | | | $6,766,239 | | | $10,240,552 | | | ($332,528) | | | $11,705,394 | |
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| 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 | |
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| Consolidated net income (a) | 4,308 | | | — | | | — | | | — | | | 159,703 | | | — | | | 164,011 | |
| Other comprehensive income | — | | | — | | | — | | | — | | | — | | | 12,540 | | | 12,540 | |
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| 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 trust | 31,636 | | | — | | | — | | | — | | | — | | | — | | | 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 | |
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| See Notes to Financial Statements. | | | | | | | | | | | | |
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| (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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| ENTERGY CORPORATION AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2021 |
| (Unaudited) |
| | | | | | | | | | | | | |
| | | Common Shareholders’ Equity | | |
| Subsidiaries’ Preferred Stock and Noncontrolling Interest | | Common
Stock | | Treasury
Stock | | Paid-in
Capital | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total |
| (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 |
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| 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 | |
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| 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 | |
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| 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 | |
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| See Notes to Financial Statements. | | | | | | | | | | | | | |
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| (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. |
ENTERGY CORPORATION AND SUBSIDIARIES
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
NOTE 1. COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions,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 JanuaryOctober 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1$83 million in favor of Entergy Nuclear PalisadesIndian 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 Palisadescombined damages case. Entergy received payment from the U.S. Treasury in February 2021.January 2022. The effectseffect of recording the judgment were reductionswas a reduction to plant, other operationasset write-offs, impairments, and maintenance expense, and taxes other than income taxes.related charges (credits). The Palisades damages awarded included $15.7$32 million related to costs previously recorded as plant, $7.1$47 million related to costs previously recorded as other operation and maintenance expenses, and $0.3$4 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Employment and Labor-related Proceedings
See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.
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-RelatedGulf - 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 2021,2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decreasean increase from $0.01052$0.00959 per kWh to $0.00959$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 calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate$0.016390 per kWh, which became effective with the first billing cycle in April 20212022 through the normal operation of the tariff.
Entergy Louisiana
InAs 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. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery throughIn April 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of thecharges in February 2021 fuel costs incurredthat did not recommend any financial disallowances, but included several prospective recommendations. Responsive testimony was filed by all LPSC-jurisdictional utilities. At its June 2021 meeting,one intervenor and the LPSC approvedparties agreed to suspend any procedural schedule and move toward settlement discussions to close the hiring of consultants to assist its staff in this review. Discovery is ongoing.matter.
In March 2021May 2022 the LPSC staff provided notice of anissued a draft audit ofreport regarding Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020.charges in February 2021 that did not propose any financial disallowances. The audit includes a review of the reasonableness of charges flowed throughLPSC staff and Entergy Louisiana’s purchased gas adjustment clause for that period.No audit report has been filed.
Entergy Corporation and Subsidiaries
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 February 2021,May 2022, Entergy Texas filed an application with the PUCT to implement aan interim fuel refund for asurcharge to collect the cumulative over-recoveryunder-recovery of approximately $75$51.7 million, thatincluding 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 planned to issueproposed that the refundinterim fuel surcharge be assessed over thea period of March through August 2021. On February 22, 2021,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 abate its fuel refundadmit evidence, to approve interim rates as requested in the initial application, and to remand the proceeding to assess how the February 2021 winter storm impactedPUCT to consider the unopposed settlement. In August 2022 the ALJ with the State Office of Administrative Hearings issued an order granting Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistentmotion, approving interim rates effective with the requirementsfirst billing cycle of September 2022, and remanding the PUCT’s rules.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
2020 Formula Rate Plan Filing
As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.
20212022 Formula Rate Plan Filing
In July 2021,2022, Entergy Arkansas filed with the APSC its 20212022 formula rate plan filing to set its formula rate for the 20222023 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 20222023 and a netting adjustment for the historical year 2020.2021. 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a 4 percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6$79.3 million. An order is requested by December 2021.
COVID-19 Orders
See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021,2022, Entergy Arkansas recordedhad a regulatory asset of $11.2$36.6 million for costs associated with the COVID-19 pandemic.
Filings with the LPSC (Entergy Louisiana)
Retail Rates - Electric
2017 Formula Rate Plan Filing
As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021 LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.
Request for Extension and Modification of Formula Rate Plan
As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.
2020 Formula Rate Plan Filing
In June 2021,May 2022, Entergy Louisiana filed its formula rate plan evaluation report for its 20202021 calendar year operations. The 20202021 test year evaluation report produced an earned return on common equity of 8.45%8.33%, with a base formula rate plan revenue increase of $63$65.3 million. Certain reductionsOther increases in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 the base formula rate plan revenueby an increase in net MISO revenues, leading to a net increase in formula rate plan revenue of $50.7$152.9 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27$86 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7$66.9 million. Subject to refund and LPSC review, the resulting changes will becomebe effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.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. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020.In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021,2022, Entergy Louisiana recordedhad a regulatory asset of $54.7$47.8 million for costs associated with the COVID-19 pandemic.
Filings with the MPSC (Entergy Mississippi)
2021Retail Rates
2022 Formula Rate Plan Filing
In March 2021,2022, Entergy Mississippi submitted its formula rate plan 20212022 test year filing and 20202021 look-back filing showing Entergy Mississippi’s earned return for the historical 20202021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 20212022 calendar year to be below the formula rate plan bandwidth. The 20212022 test year filing shows a $95.4$69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69%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 $44.3$48.6 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.
In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses.June 2023. In June 2021July 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 first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effectsSunflower Solar facility and benefits of the joint stipulation.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 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021,2022, Entergy Mississippi recordedhad a regulatory asset of $19.3$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)
2021Retail Rates
2022 Formula Rate Plan Filing
In July 2021,April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 20202021 test year filing. The 20202021 test year evaluation report, subsequently updated in a July 2022 filing, produced an earned return on equity of 6.26%6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64$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 $40$34.1 million and an increase in authorized gas revenues of $18.8$3.3 million. Entergy New Orleans also seeks to commence collecting $5.2$4.7 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review byIn July 2022 the City CouncilCouncil’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 othergas revenues. The parties over a 75-day review period, followed byhave a 25-day period to resolve any disputes amongattempt to reach an agreement on the parties. Resultingfinal amount to increase revenues, with implementation of resulting rates will be effective with the first billing cycle of November 2021September 2022 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022.
COVID-19 Orders
As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Additionally, ashowever, 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 February 2021May 2020 the City Council adoptedissued an accounting order authorizing Entergy New Orleans to establish a resolution suspending residential customer disconnectionsregulatory asset for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council.incremental COVID-19-related expenses. As of June 30, 2021,2022, Entergy New Orleans recordedhad a regulatory asset of $13.8$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 October 2020,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 $26.3$40.2 million annually, or $6.8$13.9 million in incremental annual revenues beyond Entergy Texas’s then-effectivecurrently effective DCRF rider based on its capital invested in distribution between JanuarySeptember 1, 2020 and August 31, 2020.June 30, 2021. In FebruarySeptember 2021 the administrative law judge withPUCT referred the proceeding to the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effectHearings. A procedural schedule was established with a hearing scheduled in MarchDecember 2021. In MarchDecember 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.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 May 2021March 2022 the PUCT issued an order approving the settlement.
Transmission Cost Recovery Factor (TCRF) Rider
As discussed in the Form 10-K, in October 2020,2021, 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 $51$66.1 million annually, or $31.6$15.1 million in incremental annual revenues beyond EntergyEnergy Texas’s then-effectivecurrently effective TCRF rider based on its capital invested in transmission between September 1, 2020 and July 1, 201931, 2021 and August 31, 2020. A procedural schedule was established with a hearing scheduledchanges in March 2021.approved transmission charges. In January 2022 the PUCT referred the proceeding to the State Office of Administrative Hearings. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 20212022 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in2022. In February 2022 the proceeding. In March 2021 the administrative law judgeALJ granted the motion for interim rates, admitted evidence, and remanded thisthe case to the
Entergy Corporation and Subsidiaries
Notes to Financial Statements
PUCT for consideration of a final order at a future open meeting. In June 20212022 the PUCT issued an order approving the settlement.
COVID-19 Orders
As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic.
Generation Cost Recovery RiderEntergy Louisiana
As discussed in the Form 10-K, in October 2020,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
Entergy Corporation and Subsidiaries
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 establish a generation cost recovery rider withimplement an initial annual revenue requirementinterim fuel surcharge to collect the cumulative under-recovery of approximately $91$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 begin recoveringthe 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 returnperiod of andsix 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 its capital investmentbehalf of the parties an unopposed settlement resolving all issues in the Montgomery County Power Station throughproceeding. 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 31,2022 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
2020. In December 2020, Entergy Texas filed an unopposed settlement supportingrecovery of the revenue requirement is subject to a generation cost recovery rider with an4 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 approximately $86APSC 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 ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judgeCOVID-19 pandemic.
Filings with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July LPSC (Entergy Louisiana)
Retail Rates - Electric
2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge.Formula Rate Plan Filing
In December 2020,May 2022, Entergy Texas alsoLouisiana filed its formula rate plan evaluation report for its 2021 calendar year operations. The 2021 test year evaluation report produced an applicationearned 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 amend its generation costtransmission and distribution plant in service reflected through the transmission recovery ridermechanism and distribution recovery mechanism are partly offset by an increase in net MISO revenues, leading to reflect its acquisitiona net increase in formula rate plan revenue of $152.9 million. The effects of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin waschanges to be acquiredtotal formula rate plan revenue are different for each legacy company, primarily due to differences in the future,legacy companies’ capacity cost changes, including the initial generation cost recovery rider rates proposed ineffect 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 application represent no change fromresulting changes will be effective for bills rendered during the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisitionfirst billing cycle of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.September 2022.
Entergy Arkansas Opportunity Sales Proceeding
As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit.In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule.In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.COVID-19 Orders
As discussed in the Form 10-K, in May 2019, Entergy Arkansas filedApril 2020 the LPSC issued an applicationorder authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and supporting testimonycollection of late fees imposed by LPSC orders associated with the APSC requestingCOVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of a special rider tarifflosses and expenses incurred due to recover from its retail customerscompliance with the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s requestLPSC’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 these payments. The court heldJune 30, 2022, Entergy Louisiana had a hearing in February 2021 regarding issues addressed inregulatory asset of $47.8 million for costs associated with the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.COVID-19 pandemic.
Complaints Against System EnergyFilings with the MPSC (Entergy Mississippi)
Return on Equity and Capital Structure ComplaintsRetail Rates
As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.2022 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 FERC ALJ issued an initial decision. With regardhistorical 2021 calendar year to System Energy’s authorizedbe 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 ALJ determined that the existingspecified point of adjustment of 6.70% return on equityrate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of 10.94% is no longer just and reasonable, and thatretail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual
Entergy Corporation and Subsidiaries
Notes to Financial Statements
2021 results to the replacement authorizedapproved benchmark return on equity, based on applicationrate 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 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 onformula rate plan. In accordance with 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 ratioprovisions of the proxy group usedformula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal 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 $59 million, which includes interest through June 30,2% of 2021 and the estimated resulting annual rate reduction would be approximately $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021.retail revenues, effective in April 2022.
The ALJ initial decisionIn 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 stepbasis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective 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.August 2022.
Grand Gulf Sale-leaseback Renewal ComplaintIn 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 Uncertain Tax Position Rate Base Issueits 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 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 ALJMPSC issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First,an order authorizing utilities to defer incremental costs and expenses associated with regardCOVID-19 compliance and 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’sseek future 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 remedyprudently incurred incremental costs and expenses.As of June 30, 2022, Entergy Mississippi had a regulatory asset of $13.1 million 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 liabilitiescosts 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, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permittedCOVID-19 pandemic. Entergy Mississippi received approval to recover interest on any retroactive return on enhancedthis regulatory asset through its formula 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, 2021.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 ALJ initial decision is2021 test year evaluation report, subsequently updated in a July 2022 filing, produced an interim stepearned 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 FERC litigation process,2018 rate case. The formula results in an increase in authorized electric revenues of $34.1 million and an ALJ’s determinations madeincrease 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 initial decision are not controllingagreement on the FERC. The ALJ infinal amount to increase revenues, with implementation of resulting rates effective with the initial decision acknowledges that these are issuesfirst billing cycle of first impression beforeSeptember 2022 pursuant to 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 informula rate plan tariff. For any disputed rate adjustments,
Entergy Corporation and Subsidiaries
Notes to Financial Statements
whole or in part.Refunds, if any,however, the City Council will set a procedural schedule that might be required will only become due afterextend the FERC issues its order reviewing the initial decision.process for City Council approval of disputed rate adjustments.
Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.
In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.
LPSC Authorization of Additional ComplaintsCOVID-19 Orders
As discussed in the Form 10-K, in May 2020 the LPSC authorizedCity 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 staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to2022 formula rate plan filing, Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigationNew Orleans requested recovery of rates charged by System Energy. The LPSC directive authorizes its staff to file complaints at the FERC “necessary to address these rate issues, to requestthis regulatory asset over a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”five-year period beginning September 2022.
Unit Power Sales Agreement ComplaintFilings 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 firstbase rate case was based on a 12-month test year ending December 31, 2021. Key drivers of the additional complaints was filed byrequested increase are changes in depreciation rates as the LPSC,result of a depreciation study and an increase in the APSC,return on equity. In addition, Entergy Texas included capital additions placed into service for the MPSCperiod of January 1, 2018 through December 31, 2021, including those additions currently reflected in the distribution and transmission cost recovery factor riders and the City Council in September 2020. The first complaint raises two setsgeneration cost recovery rider, all of rate allegations: violationswhich would be reset to zero as a result of this proceeding. In July 2022, the filed rate and a corresponding request for refunds for prior periods; and elements ofPUCT referred the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changesproceeding to the Unit Power Sales Agreement prospectively.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 MaySeptember 2021 the FERCPUCT 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 addressinggranting the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures,motion for interim rates, which went into effect in January 2022, admitting evidence, and holding those procedures in abeyance pendingremanding the FERC’s review ofproceeding to the initial decisionPUCT 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 Grand Gulf sale-leaseback renewal complaint discussed above. SystemForm 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 agreed thatTexas’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 hearing should be held in abeyance but sought rehearingPUCT referred the proceeding to the State Office of Administrative Hearings. In February 2022 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 Energyparties filed an appeal ofunopposed 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 FERC’s orders inALJ granted the Court ofmotion for interim rates, admitted evidence, and remanded the case to the
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Notes to Financial Statements
AppealsPUCT for consideration of a final order at a future open meeting. In June 2022 the Fifth Circuit. The appeal is currently in abeyance.PUCT issued an order approving the settlement.
Grand Gulf Prudence Complaint
The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants and System Energy during the period from March through July 2021.
Storm Cost Filings with Retail Regulators
Entergy Louisiana
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 4 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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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Notes to Financial Statements
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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Notes to Financial Statements
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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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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Notes to Financial Statements
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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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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Notes to Financial Statements
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, and Winter Storm Uri, and Hurricane Ida
InAs 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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.
In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incrementaladditional outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is
Entergy Corporation and Subsidiaries
Notes to Financial Statements
recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.
In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by thethese storms are currentlywere estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seekingsought an LPSC determination that $2.11 billion was prudently incurred and, therefore, iswas eligible for recovery from customers. Additionally, Entergy Louisiana is requestingrequested that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million iswas appropriate. In June 2021 a procedural schedule was established with a hearing in January 2022. 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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Notes to Financial Statements
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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Notes to Financial Statements
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 requested authorizationis 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 issuanceLPSC approved financing of system restoration bonds in one or more series in an aggregate principal amount of $2.18a $1 billion which includes the costs of re-establishing and funding a storm damage escrow account carryingfrom which funds were withdrawn to finance costs and unamortized debt costs on interimassociated with Hurricane Ida restoration. In June 2022, Entergy Louisiana supplemented the application with a request regarding the financing and issuancerecovery 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
InAs 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28which included $7 million in capital costs and approximately $8 million in non-capitalestimated 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 plansis 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 makeHurricane 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 separate filing at an appropriate timeprocedural 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 requesting replenishmentan application proposing a financing method for recovery of its storm reserves.costs deemed eligible for recovery.
Entergy Texas
Hurricane Laura, Hurricane Delta, and Winter Storm Uri
InAs 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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs.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 costs that arecharge effective with the subjectfirst 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 2021 application. As stated in the July 2021 application, Entergy Texas also plans to seek a separate financing order, in a separate application and docket, under the newly-enacted Subchapter J of Chapter 362022 issuance of the Public Utility Regulatory Act, titled “Lower-Cost Financing Mechanism for Securitization for Recovery of System Restoration Costs.” However, the ability to timely utilize that mechanism for securitization of the systembonds.
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Notes to Financial Statements
restoration costs that are approved for recovery is dependent on certain events outside of Entergy Texas’s control, which may necessitate utilizing the traditional structure for securitization of the system restoration costs as may be approved for recovery in the proceeding initiated in July 2021. In either event, only one financing order would ultimately be utilized for the securitization of system restoration costs approved for recovery by the PUCT. A procedural schedule was established with a hearing on the merits in September 2021.
NOTE 3. EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Louisiana)Mississippi)
Common Stock
Earnings (Loss) per Share
The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:statements of operations:
| | | | For the Three Months Ended June 30, | | For the Three Months Ended June 30, |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions, Except Per Share Data) | | (In Millions, Except Per Share Data) |
| | Income | | Shares | | $/share | | Income | | Shares | | $/share | | Income | | Shares | | $/share | | Income | | Shares | | $/share |
| Basic earnings (loss) per share | Basic earnings (loss) per share | | Basic earnings (loss) per share | |
| Net income (loss) attributable to Entergy Corporation | Net income (loss) attributable to Entergy Corporation | ($6.0) | | | 200.8 | | | ($0.03) | | | $360.5 | | | 200.2 | | | $1.80 | | Net income (loss) attributable to Entergy Corporation | $159.7 | | | 203.4 | | | $0.79 | | | ($6.0) | | | 200.8 | | | ($0.03) | |
| Average dilutive effect of: | Average dilutive effect of: | | Average dilutive effect of: | |
| Stock options | Stock options | | 0 | | | 0 | | | 0.3 | | | 0 | | Stock options | | 0.5 | | | (0.01) | | | — | | | — | |
| Other equity plans | Other equity plans | | 0 | | | 0 | | | 0.4 | | | (0.01) | | Other equity plans | | 0.5 | | | — | | | — | | | — | |
| | Equity Forwards | | Equity Forwards | | 0.3 | | | — | | | — | | | — | |
| Diluted earnings (loss) per share | Diluted earnings (loss) per share | ($6.0) | | | 200.8 | | | ($0.03) | | | $360.5 | | | 200.9 | | | $1.79 | | 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 and approximately 0.5 million for the three months ended June 30, 2020.2021.
The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:statements of operations:
| | | For the Six Months Ended June 30, | | For the Six Months Ended June 30, |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions, Except Per Share Data) | | (In Millions, Except Per Share Data) |
| | Income | | Shares | | $/share | | Income | | Shares | | $/share | | Income | | Shares | | $/share | | Income | | Shares | | $/share |
| Basic earnings per share | Basic earnings per share | | Basic earnings per share | |
| Net income attributable to Entergy Corporation | Net income attributable to Entergy Corporation | $328.6 | | | 200.7 | | | $1.64 | | | $479.2 | | | 200.0 | | | $2.40 | | Net income attributable to Entergy Corporation | $436.1 | | | 203.2 | | | $2.15 | | | $328.6 | | | 200.7 | | | $1.64 | |
| Average dilutive effect of: | Average dilutive effect of: | | Average dilutive effect of: | |
| Stock options | Stock options | | 0.4 | | | (0.01) | | | 0.5 | | | (0.01) | | Stock options | | 0.5 | | | (0.01) | | | 0.4 | | | (0.01) | |
| Other equity plans | Other equity plans | | 0.3 | | | 0 | | | 0.4 | | | 0 | | Other equity plans | | 0.4 | | | (0.01) | | | 0.3 | | | — | |
| | Equity forwards | | Equity forwards | | 0.2 | | | — | | | — | | | — | |
| Diluted earnings per share | Diluted earnings per share | $328.6 | | | 201.4 | | | $1.63 | | | $479.2 | | | 200.9 | | | $2.39 | | 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 and approximately 0.5 million for the six months ended June 30, 2020.2021.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 and $0.93 for the three months ended June 30, 2020.2021. 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 and $1.86 for the six months ended June 30, 2020.2021.
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. TheInitially, the aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement maycould 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, with aggregate compensation towhich have not been deducted from the agents of $0.5 million.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 three and six months ended June 30, 2021,2022, approximately 1 million shares under the forward sale agreementagreements were not included in the calculation of diluted common shares outstandingearnings per share because their effect would have been antidilutive.
Treasury Stock
During the six months ended June 30, 2021,2022, Entergy Corporation issued 443,060763,847 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, 2021.2022.
Retained Earnings
On July 30, 2021,29, 2022, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95$1.01 per share, payable on September 1, 2021,2022 to holders of record as of August 12, 2021.11, 2022.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 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) | | | 0 | | | 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) | |
| | | | | | | | | | | | | | | | | | | | | | | |
| 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 income | 38 | | | 6,045 | | | 2,370 | | | 8,453 | |
| Net other comprehensive income for the period | 24 | | | 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, 20202021 by component:
| | | | | | Cash flow
hedges
net
unrealized
gain (loss) | | Pension
and
other
postretirement
liabilities | | Net
unrealized
investment
gain (loss) | | | Total
Accumulated
Other
Comprehensive
Income (Loss) |
| | Cash flow
hedges
net
unrealized
gain (loss) | | Pension
and
other
postretirement
liabilities | | Net
unrealized
investment
gain (loss) | | | Total
Accumulated
Other
Comprehensive
Income (Loss) | | (In Thousands) |
| (In Thousands) | |
| Beginning balance, April 1, 2020 | $62,496 | | | ($503,173) | | | $41,690 | | | | ($398,987) | | |
| Beginning balance, April 1, 2021 | | Beginning balance, April 1, 2021 | ($861) | | | ($511,609) | | | $11,963 | | | | ($500,507) | |
| | Other comprehensive income (loss) before reclassifications | Other comprehensive income (loss) before reclassifications | 4,890 | | | 0 | | | 22,545 | | | | 27,435 | | Other comprehensive income (loss) before reclassifications | (14) | | | — | | | 648 | | | | 634 | |
| Amounts reclassified from accumulated other comprehensive income (loss) | Amounts reclassified from accumulated other comprehensive income (loss) | (30,296) | | | 17,224 | | | (3,980) | | | | (17,052) | | Amounts reclassified from accumulated other comprehensive income (loss) | (208) | | | 22,098 | | | (756) | | | | 21,134 | |
| Net other comprehensive income (loss) for the period | Net other comprehensive income (loss) for the period | (25,406) | | | 17,224 | | | 18,565 | | | | 10,383 | | Net other comprehensive income (loss) for the period | (222) | | | 22,098 | | | (108) | | | | 21,768 | |
| | Ending balance, June 30, 2020 | $37,090 | | | ($485,949) | | | $60,255 | | | | ($388,604) | | |
| Ending balance, June 30, 2021 | | Ending balance, June 30, 2021 | ($1,083) | | | ($489,511) | | | $11,855 | | | | ($478,739) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 20212022 by component:
| | | Cash flow
hedges
net
unrealized
gain (loss) | | Pension
and
other
postretirement
liabilities | | Net
unrealized
investment
gain (loss) | | Total
Accumulated
Other
Comprehensive
Income (Loss) | | Cash flow
hedges
net
unrealized
gain (loss) | | Pension
and
other
postretirement
liabilities | | Net
unrealized
investment
gain (loss) | | Total
Accumulated
Other
Comprehensive
Income (Loss) |
| | (In Thousands) | | (In Thousands) |
| Beginning balance, January 1, 2021 | $28,719 | | | ($534,576) | | | $56,650 | | | ($449,207) | | |
| Beginning balance, January 1, 2022 | | Beginning balance, January 1, 2022 | ($1,035) | | | ($338,647) | | | $7,154 | | | ($332,528) | |
| | Other comprehensive income (loss) before reclassifications | Other comprehensive income (loss) before reclassifications | 1,467 | | | 0 | | | (44,653) | | | (43,186) | | Other comprehensive income (loss) before reclassifications | (29) | | | — | | | (11,774) | | | (11,803) | |
| Amounts reclassified from accumulated other comprehensive income (loss) | Amounts reclassified from accumulated other comprehensive income (loss) | (31,269) | | | 45,065 | | | (142) | | | 13,654 | | Amounts reclassified from accumulated other comprehensive income (loss) | 77 | | | 14,373 | | | 5,843 | | | 20,293 | |
| Net other comprehensive income (loss) for the period | Net other comprehensive income (loss) for the period | (29,802) | | | 45,065 | | | (44,795) | | | (29,532) | | Net other comprehensive income (loss) for the period | 48 | | | 14,373 | | | (5,931) | | | 8,490 | |
| | Ending balance, June 30, 2021 | ($1,083) | | | ($489,511) | | | $11,855 | | | ($478,739) | | |
| Ending balance, June 30, 2022 | | 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, 20202021 by component:
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Cash flow
hedges
net
unrealized
gain (loss) | | Pension
and
other
postretirement
liabilities | | Net
unrealized
investment
gain (loss) | | | | Total
Accumulated
Other
Comprehensive
Income (Loss) |
| (In Thousands) |
| | | | | | | | | |
| | | | | | | | | |
| Beginning balance, January 1, 2020 | $84,206 | | | ($557,072) | | | $25,946 | | | | | ($446,920) | |
| | | | | | | | | |
| Other comprehensive income (loss) before reclassifications | 97,373 | | | 34,349 | | | 40,258 | | | | | 171,980 | |
| Amounts reclassified from accumulated other comprehensive income (loss) | (144,489) | | | 36,774 | | | (5,949) | | | | | (113,664) | |
| Net other comprehensive income (loss) for the period | (47,116) | | | 71,123 | | | 34,309 | | | | | 58,316 | |
| | | | | | | | | |
| Ending balance, June 30, 2020 | $37,090 | | | ($485,949) | | | $60,255 | | | | | ($388,604) | |
| | | | | | | | | | | | | | | | | | | | | | | | | |
| 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 reclassifications | 1,467 | | | — | | | (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) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 20212022 and 2020:2021:
| | | | Pension and Other
Postretirement Liabilities | | Pension and Other
Postretirement Liabilities |
| | | 2021 | | 2020 | | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Beginning balance, April 1, | Beginning balance, April 1, | | $3,920 | | | $14,029 | | Beginning balance, April 1, | | $7,665 | | | $3,920 | |
| | Amounts reclassified from accumulated other comprehensive income (loss) | Amounts reclassified from accumulated other comprehensive income (loss) | | 588 | | | (945) | | Amounts reclassified from accumulated other comprehensive income (loss) | | (491) | | | 588 | |
| Net other comprehensive income (loss) for the period | Net other comprehensive income (loss) for the period | | 588 | | | (945) | | Net other comprehensive income (loss) for the period | | (491) | | | 588 | |
| | Ending balance, June 30, | Ending balance, June 30, | | $4,508 | | | $13,084 | | 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, 20212022 and 2020:2021:
| | | Pension and Other
Postretirement Liabilities | | Pension and Other
Postretirement Liabilities |
| | | 2021 | | 2020 | | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Beginning balance, January 1, | Beginning balance, January 1, | | $4,327 | | | $4,562 | | Beginning balance, January 1, | | $8,278 | | | $4,327 | |
| | Other comprehensive income (loss) before reclassifications | | 0 | | | 10,050 | | |
| | Amounts reclassified from accumulated other comprehensive income (loss) | Amounts reclassified from accumulated other comprehensive income (loss) | | 181 | | | (1,528) | | Amounts reclassified from accumulated other comprehensive income (loss) | | (1,104) | | | 181 | |
| Net other comprehensive income (loss) for the period | Net other comprehensive income (loss) for the period | | 181 | | | 8,522 | | Net other comprehensive income (loss) for the period | | (1,104) | | | 181 | |
| | | Ending balance, June 30, | Ending balance, June 30, | | $4,508 | | | $13,084 | | Ending balance, June 30, | | $7,174 | | | $4,508 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 20212022 and 20202021 were as follows:
| | | | Amounts reclassified
from AOCI | | Income Statement Location | | Amounts reclassified
from AOCI | | Income Statement Location |
| | 2021 | | 2020 | | | | 2022 | | 2021 | | |
| | (In Thousands) | | | (In Thousands) | |
| Cash flow hedges net unrealized gain (loss) | Cash flow hedges net unrealized gain (loss) | | Cash flow hedges net unrealized gain (loss) | |
| Power contracts | Power contracts | $312 | | | $25,086 | | | Competitive business operating revenues | Power contracts | $— | | | $312 | | | Competitive business operating revenues |
| Interest rate swaps | Interest rate swaps | (48) | | | (48) | | | Miscellaneous - net | Interest rate swaps | (48) | | | (48) | | | Miscellaneous - net |
| Total realized gain (loss) on cash flow hedges | Total realized gain (loss) on cash flow hedges | 264 | | | 25,038 | | | Total realized gain (loss) on cash flow hedges | (48) | | | 264 | | |
| Income taxes | Income taxes | (56) | | | 5,258 | | | Income taxes | Income taxes | 10 | | | (56) | | | Income taxes |
| Total realized gain (loss) on cash flow hedges (net of tax) | Total realized gain (loss) on cash flow hedges (net of tax) | $208 | | | $30,296 | | | Total realized gain (loss) on cash flow hedges (net of tax) | ($38) | | | $208 | | |
| | Pension and other postretirement liabilities | Pension and other postretirement liabilities | | Pension and other postretirement liabilities | |
| Amortization of prior-service credit | Amortization of prior-service credit | $5,248 | | | $5,682 | | | (a) | Amortization of prior-service credit | $3,837 | | | $5,248 | | | (a) |
| Amortization of loss | Amortization of loss | (27,534) | | | (27,619) | | | (a) | Amortization of loss | (10,979) | | | (27,534) | | | (a) |
| | Settlement loss | Settlement loss | (6,043) | | | 0 | | | (a) | Settlement loss | (545) | | | (6,043) | | | (a) |
| Total amortization | Total amortization | (28,329) | | | (21,937) | | | Total amortization | (7,687) | | | (28,329) | | |
| Income taxes | Income taxes | 6,231 | | | 4,713 | | | Income taxes | Income taxes | 1,642 | | | 6,231 | | | Income taxes |
| Total amortization (net of tax) | Total amortization (net of tax) | ($22,098) | | | ($17,224) | | | Total amortization (net of tax) | ($6,045) | | | ($22,098) | | |
| | Net unrealized investment gain (loss) | Net unrealized investment gain (loss) | | Net unrealized investment gain (loss) | |
| Realized gain (loss) | Realized gain (loss) | $1,196 | | | $6,297 | | | Interest and investment income | Realized gain (loss) | ($3,750) | | | $1,196 | | | Interest and investment income |
| Income taxes | Income taxes | (440) | | | (2,317) | | | Income taxes | Income taxes | 1,380 | | | (440) | | | Income taxes |
| Total realized investment gain (loss) (net of tax) | Total realized investment gain (loss) (net of tax) | $756 | | | $3,980 | | | Total realized investment gain (loss) (net of tax) | ($2,370) | | | $756 | | |
| | Total reclassifications for the period (net of tax) | Total reclassifications for the period (net of tax) | ($21,134) | | | $17,052 | | | 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 |
| 2022 | | 2021 | | |
| (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 taxes | 20 | | | (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 taxes | 4,184 | | | 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 taxes | 3,402 | | | (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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the six months ended June 30, 2021 and 2020 were as follows:
| | | | | | | | | | | | | | | | | |
| Amounts reclassified
from AOCI | | Income Statement Location |
| 2021 | | 2020 | | |
| (In Thousands) | | |
| Cash flow hedges net unrealized gain (loss) | | | | | |
| Power contracts | $39,679 | | | $119,509 | | | Competitive business operating revenues |
| Interest rate swaps | (97) | | | (97) | | | Miscellaneous - net |
| Total realized gain (loss) on cash flow hedges | 39,582 | | | 119,412 | | | |
| Income taxes | (8,313) | | | 25,077 | | | Income taxes |
| Total realized gain (loss) on cash flow hedges (net of tax) | $31,269 | | | $144,489 | | | |
| | | | | |
| Pension and other postretirement liabilities | | | | | |
| Amortization of prior-service credit | $10,496 | | | $9,401 | | | (a) |
| Amortization of loss | (62,063) | | | (54,937) | | | (a) |
| | | | | |
| Settlement loss | (6,043) | | | 0 | | | (a) |
| Total amortization | (57,610) | | | (45,536) | | | |
| Income taxes | 12,545 | | | 8,762 | | | Income taxes |
| Total amortization (net of tax) | ($45,065) | | | ($36,774) | | | |
| | | | | |
| Net unrealized investment gain (loss) | | | | | |
| Realized gain (loss) | $224 | | | $9,413 | | | Interest and investment income |
| Income taxes | (82) | | | (3,464) | | | Income taxes |
| Total realized investment gain (loss) (net of tax) | $142 | | | $5,949 | | | |
| | | | | |
| Total reclassifications for the period (net of tax) | ($13,654) | | | $113,664 | | | |
(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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 20212022 and 20202021 were as follows:
| | | | Amounts reclassified
from AOCI | | Income Statement Location | | Amounts reclassified
from AOCI | | Income Statement Location |
| | 2021 | | 2020 | | | | 2022 | | 2021 | | |
| | (In Thousands) | | | (In Thousands) | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | Pension and other postretirement liabilities | |
| Amortization of prior-service credit | Amortization of prior-service credit | | $1,230 | | | $1,698 | | | (a) | Amortization of prior-service credit | | $1,158 | | | $1,230 | | | (a) |
| Amortization of loss | Amortization of loss | | (626) | | | (419) | | | (a) | Amortization of loss | | (308) | | | (626) | | | (a) |
| Settlement loss | Settlement loss | | (1,400) | | | 0 | | | (a) | Settlement loss | | (178) | | | (1,400) | | | (a) |
| Total amortization | Total amortization | | (796) | | | 1,279 | | | Total amortization | | 672 | | | (796) | | |
| Income taxes | Income taxes | | 208 | | | (334) | | | Income taxes | Income taxes | | (181) | | | 208 | | | Income taxes |
| Total amortization (net of tax) | Total amortization (net of tax) | | (588) | | | 945 | | | Total amortization (net of tax) | | 491 | | | (588) | | |
| | Total reclassifications for the period (net of tax) | Total reclassifications for the period (net of tax) | | ($588) | | | $945 | | | 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, 20212022 and 20202021 were as follows:
| | | Amounts reclassified
from AOCI | | Income Statement Location | | Amounts reclassified
from AOCI | | Income Statement Location |
| | 2021 | | 2020 | | | | 2022 | | 2021 | | |
| | (In Thousands) | | | (In Thousands) | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | Pension and other postretirement liabilities | |
| Amortization of prior-service credit | Amortization of prior-service credit | | $2,460 | | | $2,787 | | | (a) | Amortization of prior-service credit | | $2,316 | | | $2,460 | | | (a) |
| Amortization of loss | Amortization of loss | | (1,305) | | | (720) | | | (a) | Amortization of loss | | (627) | | | (1,305) | | | (a) |
| Settlement loss | Settlement loss | | (1,400) | | | 0 | | | (a) | Settlement loss | | (178) | | | (1,400) | | | (a) |
| Total amortization | Total amortization | | (245) | | | 2,067 | | | Total amortization | | 1,511 | | | (245) | | |
| Income taxes | Income taxes | | 64 | | | (539) | | | Income taxes | Income taxes | | (407) | | | 64 | | | Income taxes |
| Total amortization (net of tax) | Total amortization (net of tax) | | (181) | | | 1,528 | | | Total amortization (net of tax) | | 1,104 | | | (181) | | |
| | Total reclassifications for the period (net of tax) | Total reclassifications for the period (net of tax) | | ($181) | | | $1,528 | | | 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.
Preferred Stock
In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of June 30, 2021, no preferred stock has been issued under the new authority.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Noncontrolling Interest
The dollar value of noncontrolling interest for Entergy Louisiana as of June 30, 2022 and December 31, 2021 is presented below:
| | | | | | | | | | | |
| 2022 | | 2021 |
| (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:
| | | | | | | | | | | |
| 2022 | | 2021 |
| (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 2026.2027. 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
ended June 30, 20212022 was 1.61%1.96% on the drawn portion of the facility. Following is a summaryAs of the borrowingsJune 30, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility as of June 30, 2021.are:
| | | | | | | | | | | | | | | | | | | | |
| Capacity | | Borrowings | | Letters
of Credit | | Capacity
Available |
| (In Millions) |
| $3,500 | | $150 | | $6 | | $3,344 |
| | | | | | | | | | | | | | | | | | | | |
| Capacity | | Borrowings | | Letters
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 Registrant SubsidiariesUtility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facilityEntergy 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, 2021,2022, Entergy Corporation had approximately $866 million$1.398 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 20212022 was 0.32%0.91%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 20212022 as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Company | | Expiration
Date | | Amount of
Facility | | Interest Rate (a) | | Amount Drawn
as of
June 30, 2021 | | Letters of Credit
Outstanding as of
June 30, 2021 |
| Entergy Arkansas | | April 2022 | | $25 million (b) | | 2.75% | | $0 | | $0 |
| Entergy Arkansas | | June 2026 | | $150 million (c) | | 1.23% | | $0 | | $0 |
| Entergy Louisiana | | June 2026 | | $350 million (c) | | 1.23% | | $0 | | $0 |
| Entergy Mississippi | | April 2022 | | $37.5 million (d) | | 1.60% | | $0 | | $0 |
| Entergy Mississippi | | April 2022 | | $35 million (d) | | 1.60% | | $0 | | $0 |
| Entergy Mississippi | | April 2022 | | $10 million (d) | | 1.60% | | $0 | | $0 |
| Entergy New Orleans | | June 2024 | | $25 million (c) | | 1.58% | | $0 | | $0 |
| Entergy Texas | | June 2026 | | $150 million (c) | | 1.60% | | $0 | | $1.3 million |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Company | | Expiration
Date | | Amount of
Facility | | Interest Rate
(a) | | Amount Drawn
as of
June 30, 2022 | | Letters of Credit
Outstanding as of
June 30, 2022 |
| Entergy Arkansas | | April 2023 | | $25 million (b) | | 3.19% | | $— | | $— |
| Entergy Arkansas | | June 2027 | | $150 million (c) | | 2.75% | | $— | | $— |
| Entergy Louisiana | | June 2027 | | $350 million (c) | | 2.88% | | $— | | $— |
| Entergy Mississippi | | April 2023 | | $45 million (d) | | 3.13% | | $— | | $— |
| Entergy Mississippi | | April 2023 | | $40 million (d) | | 3.13% | | $— | | $— |
| Entergy Mississippi | | April 2023 | | $10 million (d) | | 3.13% | | $— | | $— |
| Entergy Mississippi | | July 2024 | | $150 million | | 2.42% | | $100 million | | $— |
| Entergy New Orleans | | June 2024 | | $25 million (c) | | 3.29% | | $— | | $— |
| Entergy Texas | | June 2027 | | $150 million (c) | | 2.88% | | $— | | $1.1 million |
(a)The interest rate is the estimated interest rate as of June 30, 20212022 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under thethis 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The commitment fees on the credit facilities range from 0.075% to 0.275%0.375% of the undrawn commitment amount.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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or morean uncommitted standby letter of credit facilities primarilyfacility 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, 2021:2022:
| | | | | | | | | | | | | | | | | | | | |
| Company | | Amount of
Uncommitted Facility | | Letter of Credit Fee | | MISO Letters of Credit
Issued as of
June 30, 2021 2022
(a) (b) |
| Entergy Arkansas | | $25 million | | 0.78% | | $2.54.5 million |
| Entergy Louisiana | | $125 million | | 0.78% | | $7.870.0 million |
| Entergy Mississippi | | $65 million | | 0.78% | | $24.3 million |
| Entergy New Orleans | | $15 million | | 1.00%1.625% | | $11.0 million |
| Entergy Texas | | $5080 million | | 0.70%0.875% | | $18.279.6 million |
(a)As of June 30, 2021,2022, letters of credit posted with MISO covered financial transmission rightsright exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9$0.4 million for Entergy Mississippi $0.3 million for Entergy New Orleans, and $2.3$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, 2021,2022, in addition to the $2$4.3 million MISO letterletters of credit, Entergy Mississippi has $7.9had $7 million ofin 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 July 14, 2022.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, 20212022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
| | | | | | | | | | | |
| | Authorized | | Borrowings |
| | (In Millions) |
| Entergy Arkansas | $250 | | $0 |
| Entergy Louisiana | $450 | | $0 |
| Entergy Mississippi | $175 | | $17 |
| Entergy New Orleans | $150 | | $38 |
| Entergy Texas | $200 | | $63 |
| System Energy | $200 | | $0 |
| | | | | | | | | | | |
| Authorized | | Borrowings |
| (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 Corporation and Subsidiaries
Notes to Financial Statements
Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022.2023. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2021,2022, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 20212022 was 1.71%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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 havealso issue commercial paper, programs in place. Following is a summarydetails of which follow as of June 30, 2021:2022:
| | Company | Company | | Expiration
Date | | Amount
of
Facility | | Weighted
Average Interest
Rate on
Borrowings (a) | | Amount
Outstanding as of
June 30, 2021 | Company | | Expiration
Date | | Amount
of
Facility | | Weighted
Average Interest
Rate on
Borrowings (a) | | Amount
Outstanding as of
June 30, 2022 |
| | | | | (Dollars in Millions) | | | | | (Dollars in Millions) |
| Entergy Arkansas VIE | Entergy Arkansas VIE | | June 2024 | | $80 | | 1.26% | | $0 | Entergy Arkansas VIE | | June 2025 | | $80 | | 1.55% | | $12 |
| Entergy Louisiana River Bend VIE | Entergy Louisiana River Bend VIE | | June 2024 | | $105 | | 1.22% | | $64.6 | Entergy Louisiana River Bend VIE | | June 2025 | | $105 | | 1.37% | | $20 |
| Entergy Louisiana Waterford VIE | Entergy Louisiana Waterford VIE | | June 2024 | | $105 | | 1.22% | | $62.1 | Entergy Louisiana Waterford VIE | | June 2025 | | $105 | | 1.49% | | $70.4 |
| System Energy VIE | System Energy VIE | | June 2024 | | $120 | | 1.22% | | $45.7 | System Energy VIE | | June 2025 | | $120 | | 1.54% | | $93.8 |
(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. 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, 20212022 as follows:
| | | | | | | | | | | | | | |
| Company | | Description | | Amount |
Entergy Arkansas VIE | | 3.65% Series L due July 2021 (a) | | $90 million |
| 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 |
(a) Repaid at maturity
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy Arkansas, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.
Debt Issuances and Retirements
(Entergy Corporation)Texas Securitization Bonds
In March 2021, Entergy Corporation issued $650January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.
(Entergy Arkansas)
In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.
(Entergy Louisiana)
In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related toTexas’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 Zeta,Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and the winter stormsconsolidated by Entergy Texas, issued $290.85 million of February 2021, and for general corporate purposes.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 | |
In April 2021,Although the principal amount of each tranche is not due until the dates given above, Entergy Louisiana arrangedTexas 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 the issuance by the Louisiana Local Government Environmental Facilities2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and Community Development Authority of (i) $16.2$19.4 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portionfor 2026. All of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.expected principal payments for 2022-2026 are for Tranche A-1.
(With the proceeds, Entergy Mississippi)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.
In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.
(Entergy Texas)
In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.
(System Energy)
In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together
Entergy Corporation and Subsidiaries
Notes to Financial Statements
with other funds, to refund $83.695 million of outstanding revenue bonds.
Fair Value
The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 20212022 were as follows:
| | | Book Value
of Long-Term Debt | | Fair Value
of Long-Term Debt (a) | | Book Value
of Long-Term Debt | | Fair Value
of Long-Term Debt (a) |
| | (In Thousands) | | (In Thousands) |
| Entergy | Entergy | $24,497,290 | | | $26,221,663 | | Entergy | $25,452,926 | | | $23,227,270 | |
| Entergy Arkansas | Entergy Arkansas | $4,043,714 | | | $4,327,356 | | Entergy Arkansas | $4,175,929 | | | $3,805,958 | |
| Entergy Louisiana | Entergy Louisiana | $9,836,133 | | | $10,746,564 | | Entergy Louisiana | $10,369,840 | | | $9,626,860 | |
| Entergy Mississippi | Entergy Mississippi | $1,981,674 | | | $2,166,517 | | Entergy Mississippi | $2,430,499 | | | $2,134,560 | |
| Entergy New Orleans | Entergy New Orleans | $636,870 | | | $584,209 | | Entergy New Orleans | $782,815 | | | $743,715 | |
| Entergy Texas | Entergy Texas | $2,323,879 | | | $2,496,970 | | Entergy Texas | $2,612,874 | | | $2,360,498 | |
| System Energy | System Energy | $750,939 | | | $771,477 | | 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 20202021 were as follows:
| | | Book Value
of Long-Term Debt | | Fair Value
of Long-Term Debt (a) | | Book Value
of Long-Term Debt | | Fair Value
of Long-Term Debt (a) |
| | (In Thousands) | | (In Thousands) |
| Entergy | Entergy | $22,369,776 | | | $24,813,818 | | Entergy | $25,880,901 | | | $27,061,171 | |
| Entergy Arkansas | Entergy Arkansas | $3,967,507 | | | $4,355,632 | | Entergy Arkansas | $3,958,862 | | | $4,176,577 | |
| Entergy Louisiana | Entergy Louisiana | $9,027,451 | | | $10,258,294 | | Entergy Louisiana | $10,914,346 | | | $11,492,650 | |
| Entergy Mississippi | Entergy Mississippi | $1,780,577 | | | $2,021,432 | | Entergy Mississippi | $2,179,989 | | | $2,346,230 | |
| Entergy New Orleans | Entergy New Orleans | $642,233 | | | $620,634 | | Entergy New Orleans | $788,165 | | | $765,538 | |
| Entergy Texas | Entergy Texas | $2,493,708 | | | $2,765,193 | | Entergy Texas | $2,354,148 | | | $2,483,995 | |
| System Energy | System Energy | $805,274 | | | $840,540 | | 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Stock Options
Entergy granted options on 508,704444,028 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 20212022 with a fair value of $12.27$16.25 per option. As of June 30, 2021,2022, there were options on 2,844,4462,871,099 shares of common stock outstanding with a weighted-average exercise price of $90.78.$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, 2021.2022. The aggregate intrinsic value of the stock options outstanding as of June 30, 20212022 was $41.5$56.7 million.
The following table includes financial information for outstanding stock options for the three months ended June 30, 20212022 and 2020:2021:
| | | | | | | | | | | |
| 2021 | | 2020 |
| (In Millions) |
| Compensation expense included in Entergy’s net income | $1.0 | | | $1.0 | |
| Tax benefit recognized in Entergy’s net income | $0.2 | | | $0.2 | |
| Compensation cost capitalized as part of fixed assets and materials and supplies | $0.4 | | | $0.4 | |
| | | | | | | | | | | |
| 2022 | | 2021 |
| (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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table includes financial information for outstanding stock options for the six months ended June 30, 20212022 and 2020:2021:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions) | | (In Millions) |
| Compensation expense included in Entergy’s net income | Compensation expense included in Entergy’s net income | $2.0 | | | $2.0 | | Compensation expense included in Entergy’s net income | $2.3 | | | $2.0 | |
| Tax benefit recognized in Entergy’s net income | Tax benefit recognized in Entergy’s net income | $0.5 | | | $0.5 | | Tax benefit recognized in Entergy’s net income | $0.6 | | | $0.5 | |
| Compensation cost capitalized as part of fixed assets and materials and supplies | Compensation cost capitalized as part of fixed assets and materials and supplies | $0.8 | | | $0.8 | | Compensation cost capitalized as part of fixed assets and materials and supplies | $0.8 | | | $0.8 | |
Other Equity Awards
In January 20212022 the Board approved and Entergy granted 392,382328,849 restricted stock awards and 203,983170,966 long-term incentive awards under the 2019 Omnibus Incentive Plan. The restricted stock awards were made effective on January 28, 202127, 2022 and were valued at $95.87$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, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio – was selected for the 2021-20232022-2024 performance period. Performance will be measured based 80 percent on relative total shareholder return and 20 percent on the credit measure. The performance units were granted on January 28, 202127, 2022 and 80 percent were valued at $110.74$138.99 per share based on various factors, primarily market conditions; and 20 percent were valued at $95.87$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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 and 2020:2021:
| | | | | | | | | | | |
| 2021 | | 2020 |
| (In Millions) |
| Compensation expense included in Entergy’s net income | $9.7 | | | $9.6 | |
| Tax benefit recognized in Entergy’s net income | $2.5 | | | $2.5 | |
| Compensation cost capitalized as part of fixed assets and materials and supplies | $4.0 | | | $3.8 | |
| | | | | | | | | | | |
| 2022 | | 2021 |
| (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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table includes financial information for other outstanding equity awards for the six months ended June 30, 20212022 and 2020:2021:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions) | | (In Millions) |
| Compensation expense included in Entergy’s net income | Compensation expense included in Entergy’s net income | $20.5 | | | $19.0 | | Compensation expense included in Entergy’s net income | $22.0 | | | $20.5 | |
| Tax benefit recognized in Entergy’s net income | Tax benefit recognized in Entergy’s net income | $5.2 | | | $4.9 | | Tax benefit recognized in Entergy’s net income | $5.6 | | | $5.2 | |
| Compensation cost capitalized as part of fixed assets and materials and supplies | Compensation cost capitalized as part of fixed assets and materials and supplies | $8.0 | | | $7.2 | | 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 cost,costs, including amounts capitalized, for the second quarters of 20212022 and 2020,2021, included the following components:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Service cost - benefits earned during the period | Service cost - benefits earned during the period | $42,951 | | | $40,379 | | Service cost - benefits earned during the period | $36,977 | | | $42,951 | |
| Interest cost on projected benefit obligation | Interest cost on projected benefit obligation | 47,382 | | | 60,799 | | Interest cost on projected benefit obligation | 52,676 | | | 47,382 | |
| Expected return on assets | Expected return on assets | (106,039) | | | (103,565) | | Expected return on assets | (103,085) | | | (106,039) | |
| | Amortization of net loss | Amortization of net loss | 92,799 | | | 87,259 | | Amortization of net loss | 56,413 | | | 92,799 | |
| Settlement charges | Settlement charges | 111,549 | | | 0 | | Settlement charges | 22,653 | | | 111,549 | |
| Net pension costs | Net pension costs | $188,642 | | | $84,872 | | 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:
| | | | | | | | | | | |
| 2022 | | 2021 |
| (In Thousands) |
| Service cost - benefits earned during the period | $74,637 | | | $88,191 | |
| Interest cost on projected benefit obligation | 103,795 | | | 93,480 | |
| Expected return on assets | (206,692) | | | (211,753) | |
| | | |
| Amortization of net loss | 116,992 | | | 197,190 | |
| Settlement charges | 22,653 | | | 111,549 | |
| | | |
| Net pension costs | $111,385 | | | $278,657 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components:
| | | | | | | | | | | |
| 2021 | | 2020 |
| (In Thousands) |
| Service cost - benefits earned during the period | $88,191 | | | $80,758 | |
| Interest cost on projected benefit obligation | 93,480 | | | 121,598 | |
| Expected return on assets | (211,753) | | | (207,130) | |
| | | |
| Amortization of net loss | 197,190 | | | 174,518 | |
| Settlement charges | 111,549 | | | 0 | |
| | | |
| Net pension costs | $278,657 | | | $169,744 | |
The Registrant Subsidiaries’ qualified pension cost,costs, including amounts capitalized, for their employees for the second quarters of 20212022 and 2020,2021, included the following components:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Entergy
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 obligation | | 9,761 | | | 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 loss | | 12,848 | | | 12,302 | | | 3,620 | | | 1,368 | | | 2,439 | | | 3,171 | |
| Settlement charges | | 11,496 | | | 4,461 | | | 2,208 | | | — | | | 2,466 | | | 2,023 | |
| Net pension cost | | $21,773 | | | $15,394 | | | $5,535 | | | $744 | | | $3,851 | | | $5,003 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
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 obligation | | 8,752 | | | 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 loss | | 18,250 | | | 17,890 | | | 5,309 | | | 2,069 | | | 3,415 | | | 4,933 | |
| Settlement charges | | 24,386 | | | 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 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| | (In Thousands) |
| Service cost - benefits earned during the period | | $6,566 | | | $8,794 | | | $2,023 | | | $663 | | | $1,546 | | | $1,965 | |
| Interest cost on projected benefit obligation | | 11,433 | | | 12,841 | | | 3,340 | | | 1,456 | | | 2,782 | | | 2,814 | |
| Expected return on assets | | (19,622) | | | (22,402) | | | (5,757) | | | (2,627) | | | (5,486) | | | (4,663) | |
| | | | | | | | | | | | |
| Amortization of net loss | | 16,897 | | | 16,627 | | | 4,748 | | | 2,005 | | | 3,265 | | | 4,279 | |
| Net pension cost | | $15,274 | | | $15,860 | | | $4,354 | | | $1,497 | | | $2,107 | | | $4,395 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Entergy
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 obligation | | 19,078 | | | 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 loss | | 26,274 | | | 24,899 | | | 7,430 | | | 2,736 | | | 4,994 | | | 6,437 | |
| Settlement charges | | 11,496 | | | 4,461 | | | 2,208 | | | — | | | 2,466 | | | 2,023 | |
| Net pension cost | | $32,127 | | | $26,494 | | | $8,950 | | | $1,488 | | | $5,276 | | | $8,029 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
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 obligation | | 17,092 | | | 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 loss | | 37,552 | | | 37,093 | | | 10,976 | | | 4,340 | | | 7,126 | | | 10,258 | |
| Settlement charges | | 24,386 | | | 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 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| | (In Thousands) |
| Service cost - benefits earned during the period | | $13,132 | | | $17,588 | | | $4,046 | | | $1,326 | | | $3,092 | | | $3,930 | |
| Interest cost on projected benefit obligation | | 22,866 | | | 25,682 | | | 6,680 | | | 2,912 | | | 5,564 | | | 5,628 | |
| Expected return on assets | | (39,244) | | | (44,804) | | | (11,514) | | | (5,254) | | | (10,972) | | | (9,326) | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| Amortization of net loss | | 33,794 | | | 33,254 | | | 9,496 | | | 4,010 | | | 6,530 | | | 8,558 | |
| Net pension cost | | $30,548 | | | $31,720 | | | $8,708 | | | $2,994 | | | $4,214 | | | $8,790 | |
Non-Qualified Net Pension Cost
Entergy recognized $4.6$7.2 million and $4.5$4.6 million in pension cost for its non-qualified pension plans in the second quarters of 2022 and 2021, and 2020, 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 $9.2$17.4 million and $9.1$9.2 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2022 and 2021, and 2020.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 20212022 and 2020:2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas |
| (In Thousands) |
| 2021 | $90 | | | $44 | | | $96 | | | $8 | | | $115 | |
| 2020 | $83 | | | $37 | | | $90 | | | $8 | | | $117 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 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, 20212022 and 2020:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas |
| (In Thousands) |
| 2021 | $180 | | | $88 | | | $192 | | | $16 | | | $230 | |
| 2020 | $166 | | | $74 | | | $180 | | | $16 | | | $234 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Components of Net Other Postretirement Benefit Cost (Income)
Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 20212022 and 2020,2021, included the following components:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Service cost - benefits earned during the period | Service cost - benefits earned during the period | $6,645 | | | $6,231 | | Service cost - benefits earned during the period | $6,184 | | | $6,645 | |
| Interest cost on accumulated postretirement benefit obligation (APBO) | Interest cost on accumulated postretirement benefit obligation (APBO) | 5,320 | | | 6,888 | | Interest cost on accumulated postretirement benefit obligation (APBO) | 6,827 | | | 5,320 | |
| Expected return on assets | Expected return on assets | (10,805) | | | (10,182) | | Expected return on assets | (10,855) | | | (10,805) | |
| | Amortization of prior service credit | Amortization of prior service credit | (8,267) | | | (8,985) | | Amortization of prior service credit | (6,388) | | | (8,267) | |
| Amortization of net loss | Amortization of net loss | 713 | | | 1,005 | | Amortization of net loss | 1,083 | | | 713 | |
| Net other postretirement benefit income | Net other postretirement benefit income | ($6,394) | | | ($5,043) | | Net other postretirement benefit income | ($3,149) | | | ($6,394) | |
Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 20212022 and 2020,2021, included the following components:
| | | | | | | | | | | |
| | 2021 | | 2020 |
| | (In Thousands) |
| Service cost - benefits earned during the period | $13,290 | | | $12,032 | |
| Interest cost on accumulated postretirement benefit obligation (APBO) | 10,640 | | | 14,820 | |
| Expected return on assets | (21,610) | | | (20,510) | |
| | | |
| Amortization of prior service credit | (16,534) | | | (14,907) | |
| Amortization of net loss | 1,426 | | | 1,473 | |
| Net other postretirement benefit income | ($12,788) | | | ($7,092) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | |
| | 2022 | | 2021 |
| | (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 loss | 2,166 | | | 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 20212022 and 2020,2021, included the following components:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
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 APBO | | 932 | | | 1,130 | | | 278 | | | 130 | | | 317 | | | 220 | |
| Expected return on assets | | (4,505) | | | 0 | | | (1,384) | | | (1,438) | | | (2,548) | | | (789) | |
| | | | | | | | | | | | |
| Amortization of prior service credit | | (280) | | | (1,230) | | | (444) | | | (229) | | | (936) | | | (109) | |
| Amortization of net (gain) loss | | 49 | | | (91) | | | 19 | | | (178) | | | 100 | | | 15 | |
| Net other postretirement benefit cost (income) | | ($2,770) | | | $1,353 | | | ($1,169) | | | ($1,606) | | | ($2,721) | | | ($328) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Entergy
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 APBO | | 1,263 | | | 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) loss | | 218 | | | (186) | | | 56 | | | (225) | | | 162 | | | 30 | |
| Net other postretirement benefit cost (income) | | ($1,417) | | | $1,507 | | | ($1,092) | | | ($1,680) | | | ($2,769) | | | ($252) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| | (In Thousands) |
| Service cost - benefits earned during the period | | $933 | | | $1,524 | | | $372 | | | $114 | | | $306 | | | $321 | |
| Interest cost on APBO | | 1,164 | | | 1,497 | | | 372 | | | 186 | | | 477 | | | 276 | |
| Expected return on assets | | (4,260) | | | 0 | | | (1,287) | | | (1,344) | | | (2,403) | | | (735) | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| Amortization of prior service credit | | (396) | | | (1,695) | | | (444) | | | (228) | | | (939) | | | (282) | |
| Amortization of net (gain) loss | | 162 | | | (81) | | | 48 | | | 9 | | | 231 | | | 33 | |
| Net other postretirement benefit cost (income) | | ($2,397) | | | $1,245 | | | ($939) | | | ($1,263) | | | ($2,328) | | | ($387) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
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 APBO | | 932 | | | 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) loss | | 49 | | | (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, 20212022 and 2020,2021, included the following components:
| | 2021 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy | |
| 2022 | | 2022 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| | | (In Thousands) | | | (In Thousands) |
| Service cost - benefits earned during the period | Service cost - benefits earned during the period | | $2,068 | | | $3,088 | | | $724 | | | $218 | | | $692 | | | $670 | | Service cost - benefits earned during the period | | $2,228 | | | $2,816 | | | $678 | | | $198 | | | $662 | | | $620 | |
| Interest cost on APBO | Interest cost on APBO | | 1,864 | | | 2,260 | | | 556 | | | 260 | | | 634 | | | 440 | | Interest cost on APBO | | 2,526 | | | 2,886 | | | 700 | | | 348 | | | 798 | | | 558 | |
| Expected return on assets | Expected return on assets | | (9,010) | | | 0 | | | (2,768) | | | (2,876) | | | (5,096) | | | (1,578) | | Expected return on assets | | (8,966) | | | — | | | (2,788) | | | (2,998) | | | (5,136) | | | (1,582) | |
| Amortization of prior service credit | | (560) | | | (2,460) | | | (888) | | | (458) | | | (1,872) | | | (218) | | |
| Amortization of prior service cost/(credit) | | Amortization of prior service cost/(credit) | | 942 | | | (2,316) | | | (886) | | | (458) | | | (2,186) | | | (160) | |
| Amortization of net (gain) loss | Amortization of net (gain) loss | | 98 | | | (182) | | | 38 | | | (356) | | | 200 | | | 30 | | Amortization of net (gain) loss | | 436 | | | (372) | | | 112 | | | (450) | | | 324 | | | 60 | |
| Net other postretirement benefit cost (income) | Net other postretirement benefit cost (income) | | ($5,540) | | | $2,706 | | | ($2,338) | | | ($3,212) | | | ($5,442) | | | ($656) | | Net other postretirement benefit cost (income) | | ($2,834) | | | $3,014 | | | ($2,184) | | | ($3,360) | | | ($5,538) | | | ($504) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
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 APBO | | 1,864 | | | 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) loss | | 98 | | | (182) | | | 38 | | | (356) | | | 200 | | | 30 | |
| Net other postretirement benefit cost (income) | | ($5,540) | | | $2,706 | | | ($2,338) | | | ($3,212) | | | ($5,442) | | | ($656) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| | (In Thousands) |
| Service cost - benefits earned during the period | | $1,761 | | | $2,947 | | | $723 | | | $219 | | | $609 | | | $615 | |
| Interest cost on APBO | | 2,381 | | | 3,220 | | | 794 | | | 413 | | | 1,059 | | | 583 | |
| Expected return on assets | | (8,586) | | | 0 | | | (2,594) | | | (2,699) | | | (4,838) | | | (1,483) | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| Amortization of prior service credit | | (1,057) | | | (2,784) | | | (765) | | | (304) | | | (1,489) | | | (501) | |
| Amortization of net (gain) loss | | 217 | | | (280) | | | 77 | | | (29) | | | 443 | | | 53 | |
| Net other postretirement benefit cost (income) | | ($5,284) | | | $3,103 | | | ($1,765) | | | ($2,400) | | | ($4,216) | | | ($733) | |
Reclassification out of Accumulated Other Comprehensive Income (Loss)
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 20212022 and 2020:2021:
| | 2021 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total | |
| 2022 | | 2022 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total |
| | | (In Thousands) | | | | | (In Thousands) | | |
| Entergy | Entergy | | Entergy | |
| Amortization of prior service (cost) credit | Amortization of prior service (cost) credit | | $0 | | | $5,288 | | | ($40) | | | $5,248 | | Amortization of prior service (cost) credit | | $— | | | $4,014 | | | ($177) | | | $3,837 | |
| Amortization of net loss | Amortization of net loss | | (26,443) | | | (496) | | | (595) | | | (27,534) | | Amortization of net loss | | (10,035) | | | (596) | | | (348) | | | (10,979) | |
| | Settlement loss | Settlement loss | | (6,043) | | | 0 | | | 0 | | | (6,043) | | Settlement loss | | (178) | | | — | | | (367) | | | (545) | |
| | ($32,486) | | | $4,792 | | | ($635) | | | ($28,329) | | | ($10,213) | | | $3,418 | | | ($892) | | | ($7,687) | |
| Entergy Louisiana | Entergy Louisiana | | | | | | | | | Entergy Louisiana | | | | | | | | |
| Amortization of prior service credit | Amortization of prior service credit | | $0 | | | $1,230 | | | $0 | | | $1,230 | | Amortization of prior service credit | | $— | | | $1,158 | | | $— | | | $1,158 | |
| Amortization of net gain (loss) | Amortization of net gain (loss) | | (716) | | | 91 | | | (1) | | | (626) | | Amortization of net gain (loss) | | (493) | | | 186 | | | (1) | | | (308) | |
| Settlement loss | Settlement loss | | (1,400) | | | 0 | | | 0 | | | ($1,400) | | Settlement loss | | (178) | | | — | | | — | | | ($178) | |
| | ($2,116) | | | $1,321 | | | ($1) | | | ($796) | | | ($671) | | | $1,344 | | | ($1) | | | $672 | |
| | 2020 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total | |
| 2021 | | 2021 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total |
| | | (In Thousands) | | | | | (In Thousands) | | |
| Entergy | Entergy | | Entergy | |
| Amortization of prior service (cost) credit | Amortization of prior service (cost) credit | | $0 | | | $5,739 | | | ($57) | | | $5,682 | | Amortization of prior service (cost) credit | | $— | | | $5,288 | | | ($40) | | | $5,248 | |
| Amortization of net loss | Amortization of net loss | | (26,461) | | | (327) | | | (831) | | | (27,619) | | Amortization of net loss | | (26,443) | | | (496) | | | (595) | | | (27,534) | |
| | Settlement loss | | Settlement loss | | (6,043) | | | — | | | — | | | (6,043) | |
| | ($26,461) | | | $5,412 | | | ($888) | | | ($21,937) | | | ($32,486) | | | $4,792 | | | ($635) | | | ($28,329) | |
| Entergy Louisiana | Entergy Louisiana | | | | | | | | | Entergy Louisiana | | | | | | | | |
| Amortization of prior service credit | Amortization of prior service credit | | $0 | | | $1,698 | | | $0 | | | $1,698 | | Amortization of prior service credit | | $— | | | $1,230 | | | $— | | | $1,230 | |
| Amortization of net gain (loss) | Amortization of net gain (loss) | | (499) | | | 81 | | | (1) | | | (419) | | Amortization of net gain (loss) | | (716) | | | 91 | | | (1) | | | (626) | |
| Settlement loss | | Settlement loss | | (1,400) | | | — | | | — | | | (1,400) | |
| | ($499) | | | $1,779 | | | ($1) | | | $1,279 | | | ($2,116) | | | $1,321 | | | ($1) | | | ($796) | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 and 2020:2021:
| | 2021 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total | |
| 2022 | | 2022 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total |
| | | (In Thousands) | | | | | (In Thousands) | | |
| Entergy | Entergy | | Entergy | |
| Amortization of prior service (cost) credit | Amortization of prior service (cost) credit | | $0 | | | $10,576 | | | ($80) | | | $10,496 | | Amortization of prior service (cost) credit | | $— | | | $8,028 | | | ($354) | | | $7,674 | |
| Amortization of net loss | Amortization of net loss | | (59,883) | | | (990) | | | (1,190) | | | (62,063) | | Amortization of net loss | | (22,945) | | | (1,192) | | | (767) | | | (24,904) | |
| | Settlement loss | Settlement loss | | (6,043) | | | 0 | | | 0 | | | (6,043) | | Settlement loss | | (178) | | | — | | | (1,149) | | | (1,327) | |
| | ($65,926) | | | $9,586 | | | ($1,270) | | | ($57,610) | | | ($23,123) | | | $6,836 | | | ($2,270) | | | ($18,557) | |
| Entergy Louisiana | Entergy Louisiana | | | | | | | | | Entergy Louisiana | | | | | | | | |
| Amortization of prior service credit | Amortization of prior service credit | | $0 | | | $2,460 | | | $0 | | | $2,460 | | Amortization of prior service credit | | $— | | | $2,316 | | | $— | | | $2,316 | |
| Amortization of net gain (loss) | Amortization of net gain (loss) | | (1,484) | | | 182 | | | (3) | | | (1,305) | | Amortization of net gain (loss) | | (997) | | | 372 | | | (2) | | | (627) | |
| Settlement loss | Settlement loss | | (1,400) | | | 0 | | | 0 | | | (1,400) | | Settlement loss | | (178) | | | — | | | — | | | (178) | |
| | ($2,884) | | | $2,642 | | | ($3) | | | ($245) | | | ($1,175) | | | $2,688 | | | ($2) | | | $1,511 | |
| | 2020 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total | |
| 2021 | | 2021 | | Qualified
Pension
Costs | | Other
Postretirement
Costs | | Non-Qualified
Pension Costs | | Total |
| | | (In Thousands) | | | | | (In Thousands) | | |
| Entergy | Entergy | | Entergy | |
| Amortization of prior service (cost) credit | Amortization of prior service (cost) credit | | $0 | | | $9,516 | | | ($115) | | | $9,401 | | Amortization of prior service (cost) credit | | $— | | | $10,576 | | | ($80) | | | $10,496 | |
| Amortization of net loss | Amortization of net loss | | (52,923) | | | (352) | | | (1,662) | | | (54,937) | | Amortization of net loss | | (59,883) | | | (990) | | | (1,190) | | | (62,063) | |
| | Settlement loss | | Settlement loss | | (6,043) | | | — | | | — | | | (6,043) | |
| | ($52,923) | | | $9,164 | | | ($1,777) | | | ($45,536) | | | ($65,926) | | | $9,586 | | | ($1,270) | | | ($57,610) | |
| Entergy Louisiana | Entergy Louisiana | | | | | | | | | Entergy Louisiana | | | | | | | | |
| Amortization of prior service credit | Amortization of prior service credit | | $0 | | | $2,787 | | | $0 | | | $2,787 | | Amortization of prior service credit | | $— | | | $2,460 | | | $— | | | $2,460 | |
| Amortization of net gain (loss) | Amortization of net gain (loss) | | (998) | | | 280 | | | (2) | | | (720) | | Amortization of net gain (loss) | | (1,484) | | | 182 | | | (3) | | | (1,305) | |
| Settlement loss | | Settlement loss | | (1,400) | | | — | | | — | | | (1,400) | |
| | ($998) | | | $3,067 | | | ($2) | | | $2,067 | | | ($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.
Other Postretirement Benefits
In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Qualified Pension Settlement Cost
In the second quarter of 2021, year-to-dateYear-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021Plan’s 2022 service and interest cost, resulting in a settlement cost of $111.5 million. costs.In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’plan’s pension liability.Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. costs.Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same
Entergy Corporation and Subsidiaries
Notes to Financial Statements
manner that labor costs were charged.Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi and Entergy New Orleanseach received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.
Entergy Texas Reserve
In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduledbase rate case that was filed with the PUCT rate casein July 2022 and a reasonable amortization period will be determined by the PUCT at that time.PUCT. At June 30, 2021,2022, the balance in this reserve was approximately $10.1$15.7 million.
Employer Contributions
Based on current assumptions, Entergy expects to contribute $356$200 million to its qualified pension plans in 2021.2022. As of June 30, 2021,2022, Entergy had contributed $220.1$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 2021:2022:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New Orleans | | Entergy
Texas | | System
Energy |
| (In Thousands) |
| Expected 2021 pension contributions | $66,649 | | | $59,882 | | | $13,715 | | | $5,395 | | | $6,955 | | | $18,663 | |
| Pension contributions made through June 2021 | $36,457 | | | $39,400 | | | $7,771 | | | $3,551 | | | $4,275 | | | $10,671 | |
| Remaining estimated pension contributions to be made in 2021 | $30,192 | | | $20,482 | | | $5,944 | | | $1,844 | | | $2,680 | | | $7,992 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
NOTE 7. BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy’s reportable segments as of June 30, 20212022 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy’s segment financial information for the second quarters of 2022 and 2021 and 2020 waswere as follows:
| | | | Utility | | Entergy
Wholesale
Commodities | | All Other | | Eliminations | | Consolidated |
| | Utility | | Entergy
Wholesale
Commodities | | All Other | | Eliminations | | Entergy | | (In Thousands) |
| 2022 | | 2022 | |
| Operating revenues | | Operating revenues | | $3,306,269 | | | $88,933 | | | $— | | | ($6) | | | $3,395,196 | |
| Income taxes | | Income taxes | | ($371,704) | | | $25,233 | | | ($13,172) | | | $— | | | ($359,643) | |
| Consolidated net income (loss) | | Consolidated net income (loss) | | $156,548 | | | $87,386 | | | ($36,672) | | | ($43,251) | | | $164,011 | |
| | (In Thousands) | |
| 2021 | 2021 | | 2021 | |
| Operating revenues | Operating revenues | | $2,673,385 | | | $148,656 | | | $31 | | | ($2) | | | $2,822,070 | | Operating revenues | | $2,673,385 | | | $148,656 | | | $31 | | | ($2) | | | $2,822,070 | |
| Income taxes | Income taxes | | $71,360 | | | ($71,696) | | | ($18,080) | | | $0 | | | ($18,416) | | Income taxes | | $71,360 | | | ($71,696) | | | ($18,080) | | | $— | | | ($18,416) | |
| Consolidated net income (loss) | Consolidated net income (loss) | | $329,936 | | | ($274,648) | | | ($24,784) | | | ($31,898) | | | ($1,394) | | Consolidated net income (loss) | | $329,936 | | | ($274,648) | | | ($24,784) | | | ($31,898) | | | ($1,394) | |
| | 2020 | | |
| Operating revenues | | $2,213,061 | | | $199,709 | | | $18 | | | $0 | | | $2,412,788 | | |
| Income taxes | | $73,710 | | | $24,467 | | | ($9,062) | | | $0 | | | $89,115 | | |
| Consolidated net income (loss) | | $348,902 | | | $85,178 | | | ($37,069) | | | ($31,898) | | | $365,113 | | |
|
Entergy’s segment financial information for the six months ended June 30, 2022 and 2021 and 2020 waswere as follows:
| | | Utility | | Entergy
Wholesale
Commodities | | All Other | | Eliminations | | Consolidated | | Utility | | Entergy
Wholesale
Commodities | | All Other | | Eliminations | | Consolidated |
| | (In Thousands) | | (In Thousands) |
| 2022 | | 2022 | |
| Operating revenues | | Operating revenues | | $6,034,425 | | | $238,711 | | | $— | | | ($14) | | | $6,273,122 | |
| Income taxes | | Income taxes | | ($296,346) | | | $28,089 | | | ($24,888) | | | $— | | | ($293,145) | |
| Consolidated net income (loss) | | Consolidated net income (loss) | | $499,704 | | | $95,245 | | | ($76,148) | | | ($75,197) | | | $443,604 | |
| Total assets as of June 30, 2022 | | Total assets as of June 30, 2022 | | $60,525,686 | | | $528,296 | | | $548,740 | | | ($3,775,143) | | | $57,827,579 | |
| 2021 | 2021 | | 2021 | |
| Operating revenues | Operating revenues | | $5,270,000 | | | $396,874 | | | $54 | | | ($21) | | | $5,666,907 | | Operating revenues | | $5,270,000 | | | $396,874 | | | $54 | | | ($21) | | | $5,666,907 | |
| Income taxes | Income taxes | | $131,094 | | | ($56,135) | | | ($27,433) | | | $0 | | | $47,526 | | Income taxes | | $131,094 | | | ($56,135) | | | ($27,433) | | | $— | | | $47,526 | |
| Consolidated net income (loss) | Consolidated net income (loss) | | $690,535 | | | ($236,525) | | | ($52,464) | | | ($63,796) | | | $337,750 | | Consolidated net income (loss) | | $690,535 | | | ($236,525) | | | ($52,464) | | | ($63,796) | | | $337,750 | |
| Total assets as of June 30, 2021 | | $56,240,370 | | | $1,209,209 | | | $496,043 | | | ($1,996,339) | | | $55,949,283 | | |
| 2020 | | |
| Operating revenues | | $4,307,690 | | | $532,258 | | | $29 | | | ($10) | | | $4,839,967 | | |
| Income taxes | | $20,761 | | | ($6,073) | | | $3,233 | | | $0 | | | $17,921 | | |
| Consolidated net income (loss) | | $672,751 | | | ($25,251) | | | ($95,298) | | | ($63,796) | | | $488,406 | | |
| Total assets as of December 31, 2020 | | $55,940,153 | | | $3,800,378 | | | $552,632 | | | ($2,053,951) | | | $58,239,212 | | |
| Total assets as of December 31, 2021 | | 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 wereare primarily intersegment activity. Almost all of Entergy’s goodwill wasis 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.
Total restructuring charges for the second quarters of 20212022 and 20202021 were comprised of the following:
| | | | 2021 | | 2020 | | 2022 | | 2021 |
| | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total |
| | | (In Millions) | | (In Millions) |
| Balance as of April 1, | Balance as of April 1, | $157 | | | $14 | | | $171 | | | $150 | | | $14 | | | $164 | | Balance as of April 1, | $41 | | | $— | | | $41 | | | $157 | | | $14 | | | $171 | |
| Restructuring costs accrued | Restructuring costs accrued | (6) | | | 1 | | | (5) | | | 17 | | | 0 | | | 17 | | Restructuring costs accrued | (1) | | | — | | | (1) | | | (6) | | | 1 | | | (5) | |
| | Cash paid out | Cash paid out | 118 | | | 15 | | | 133 | | | 14 | | | 0 | | | 14 | | Cash paid out | — | | | — | | | — | | | 118 | | | 15 | | | 133 | |
| Balance as of June 30, | Balance as of June 30, | $33 | | | $0 | | | $33 | | | $153 | | | $14 | | | $167 | | Balance as of June 30, | $40 | | | $— | | | $40 | | | $33 | | | $— | | | $33 | |
In addition, Entergy Wholesale Commodities incurredrecorded 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 and $7 million in the second quarter 2020 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, 20212022 and 20202021 were comprised of the following:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total | | Employee retention and severance
expenses and other benefits-related costs | | Contracted economic development costs | | Total |
| | | (In Millions) | | (In Millions) |
| Balance as of January 1, | Balance as of January 1, | $145 | | | $14 | | | $159 | | | $129 | | | $14 | | | $143 | | Balance as of January 1, | $37 | | | $— | | | $37 | | | $145 | | | $14 | | | $159 | |
| Restructuring costs accrued | Restructuring costs accrued | 7 | | | 1 | | | 8 | | | 38 | | | 0 | | | 38 | | Restructuring costs accrued | 3 | | | — | | | 3 | | | 7 | | | 1 | | | 8 | |
| Cash paid out | Cash paid out | 119 | | | 15 | | | 134 | | | 14 | | | 0 | | | 14 | | Cash paid out | — | | | — | | | — | | | 119 | | | 15 | | | 134 | |
| Balance as of June 30, | Balance as of June 30, | $33 | | | $0 | | | $33 | | | $153 | | | $14 | | | $167 | | Balance as of June 30, | $40 | | | $— | | | $40 | | | $33 | | | $— | | | $33 | |
In addition, Entergy Wholesale Commodities incurredrecorded 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 and $12 million in the six months ended June 30, 2020 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022.
Registrant Subsidiaries
Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
NOTE 8. RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk
In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.
The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.
As a wholesale generator, Entergy Wholesale Commodities’ core business iswas 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Derivatives
Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.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. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 TWh.
Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.
Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants containcontained provisions that requirerequired 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 iswas an Entergy Corporation guarantee. If the Entergy Corporation credit rating fallsfell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, thereThere were no outstanding derivative contracts held by Entergy Wholesale Commodities.Commodities as of June 30, 2022 and December 31, 2021. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5June 30, 2022, $12 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39counterparties. As of December 31, 2021, $8 million in letters of credit werecash collateral was required to be posted by it counterparties to the Entergy subsidiary.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 hadhas executed natural gas swaps and options as of June 30, 2021 was 2.752022 is 1.75 years for Entergy Louisiana and the maximum length of time over which Entergy hadhas executed natural gas swaps as of June 30, 2021 was 92022 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, 2021 was 33,969,6002022 is 27,681,400 MMBtu for Entergy, including 20,100,00012,800,000 MMBtu for Entergy Louisiana, 13,569,00014,771,300 MMBtu for Entergy Mississippi, and 300,600110,100 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
During the second quarter 2021,2022, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 20212022 through May 31, 2022.2023. 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2021 was 126,1492022 is 135,179 GWh for Entergy, including 25,50530,477 GWh for Entergy Arkansas, 58,28061,242 GWh for Entergy Louisiana, 14,63414,621 GWh for Entergy Mississippi, 5,8425,720 GWh for Entergy New Orleans, and 21,39922,950 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2022 and December 31, 2020.2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi Entergy New Orleans, and Entergy Texas as of June 30, 20212022 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.2021.
The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 20212022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
| | Instrument | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Business | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Business |
| | | | | (In Millions) | | | | | | | (In Millions) | | |
| | Derivatives not designated as hedging instruments | Derivatives not designated as hedging instruments | | Derivatives not designated as hedging instruments | |
| Assets: | Assets: | | Assets: | |
| | Natural gas swaps and options | Natural gas swaps and options | | Prepayments and other (current portion) | | $15 | | $0 | | $15 | | Utility | Natural gas swaps and options | | Prepayments and other | | $37 | | $— | | $37 | | Utility |
| | Natural gas swaps and options | | Natural gas swaps and options | | Other deferred debits and other assets | | $9 | | $— | | $9 | | Utility |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $16 | | ($1) | | $15 | | Utility and Entergy Wholesale Commodities | Financial transmission rights | | Prepayments and other | | $13 | | ($1) | | $12 | | Utility and Entergy Wholesale Commodities |
|
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 20202021 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
| | Instrument | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Business | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Business |
| | | | | (In Millions) | | | | | | | (In Millions) | | |
| Derivatives designated as hedging instruments | | | | | | | | | |
| Assets: | | | | | | | | | |
| Electricity swaps and options | | Prepayments and other (current portion) | | $39 | | ($1) | | $38 | | Entergy Wholesale Commodities | |
| | Liabilities: | | | | | | | | | |
| Electricity swaps and options | | Other current liabilities (current portion) | | $1 | | ($1) | | $0 | | Entergy Wholesale Commodities | |
| | | Derivatives not designated as hedging instruments | Derivatives not designated as hedging instruments | | | | | | | | | Derivatives not designated as hedging instruments | | | | | | | | |
| Assets: | Assets: | | | | | | | | | Assets: | | | | | | | | |
| | Natural gas swaps and options | Natural gas swaps and options | | Prepayments and other (current portion) | | $1 | | $0 | | $1 | | Utility | Natural gas swaps and options | | Prepayments and other | | $6 | | $— | | $6 | | Utility |
| Natural gas swaps and options | Natural gas swaps and options | | Other deferred debits and other assets (non-current portion) | | $1 | | $0 | | $1 | | Utility | Natural gas swaps and options | | Other deferred debits and other assets | | $5 | | $— | | $5 | | Utility |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $9 | | $0 | | $9 | | Utility and Entergy Wholesale Commodities | Financial transmission rights | | Prepayments and other | | $4 | | $— | | $4 | | Utility and Entergy Wholesale Commodities |
| | Liabilities: | Liabilities: | | | | | | | | | Liabilities: | | | | | | | | |
| | Natural gas swaps and options | Natural gas swaps and options | | Other current liabilities (current portion) | | $6 | | $0 | | $6 | | Utility | Natural gas swaps and options | | Other current liabilities | | $7 | | $— | | $7 | | Utility |
| Natural gas swaps and options | | Other non-current liabilities (non-current portion) | | $1 | | $0 | | $1 | | Utility | |
|
(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet
(d)Excludes cash collateral in the amount of $5$12 million posted as of June 30, 20212022 and $5$8 million posted as of December 31, 2020.2021. 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, and $1which 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:
| | | | | | | | | | | | | | | | | | | | |
| Instrument | | Amount of gain (loss)
recognized in other
comprehensive income | | Income Statement location | | Amount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a) |
| | (In Millions) | | | | (In Millions) |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Electricity swaps and options | | $2 | | Competitive businesses operating revenues | | $40 |
(a) Before taxes of $8 million posted and $39 million held as of December 31, 2020.for the six months ended June 30, 2021
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The effectsPrior to the expiration of Entergy’sthe Entergy Wholesale Commodities portfolio of derivative instruments, designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2021 and 2020 were as follows:
| | | | | | | | | | | | | | | | | | | | |
| | | | | | |
| Instrument | | Amount of gain (loss)
recognized in other
comprehensive
income | | Income Statement location | | Amount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a) |
| | (In Millions) | | | | (In Millions) |
| 2021 | | | | | | |
| Electricity swaps and options | | $0 | | Competitive businesses operating revenues | | $0 |
| | | | | | |
| 2020 | | | | | | |
| Electricity swaps and options | | ($7) | | Competitive businesses operating revenues | | $25 |
(a)Before taxes of $5 million for the three months ended June 30, 2020
The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows:
| | | | | | | | | | | | | | | | | | | | |
| Instrument | | Amount of gain (loss)
recognized in other
comprehensive income | | Income Statement location | | Amount of gain
(loss)
reclassified from
accumulated
other
comprehensive
income into
income (a) |
| | (In Millions) | | | | (In Millions) |
| 2021 | | | | | | |
| Electricity swaps and options | | $2 | | Competitive businesses operating revenues | | $40 |
| | | | | | |
| 2020 | | | | | | |
| Electricity swaps and options | | $60 | | Competitive businesses operating revenues | | $120 |
(a)Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively
Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales.
Entergy may have effectively liquidateliquidated 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 continuewould have continued to be deferred in other comprehensive income until they arewere included in income as the original hedged transaction occurs.occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract arewere recorded as assets or liabilities on the balance sheet and offset as they flowflowed through to earnings.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements of operations for the three months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | |
| | | | |
| Instrument | | Income Statement
location | | Amount of gain (loss)
recorded in the income statement |
| | | | (In Millions) |
| 2022 | | | | |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | $23 |
| Financial transmission rights | | Purchased power expense | (b) | $37 |
| | | | |
| | | | |
| 2021 | | | | |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | $18 |
| Financial transmission rights | | Purchased power expense | (b) | $16 |
| Electricity swaps and options (c) | | Competitive business operating revenues | | $0 |
| | | | |
2020 | | | | |
Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | ($3) |
Financial transmission rights | | Purchased power expense | (b) | $15 |
Electricity swaps and options (c) | | Competitive business operating revenues | | ($2)— |
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements of operations for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | |
| Instrument | | Income Statement
location | | Amount of gain (loss)
recorded in the income statement |
| | | | (In Millions) |
| 2022 | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | $78 |
| Financial transmission rights | | Purchased power | (b) | $60 |
| | | | |
| | | | |
| 2021 | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | $25 |
| Financial transmission rights | | Purchased power expense | (b) | $144 |
| Electricity swaps and options (c) | | Competitive business operating revenues | | ($2) |
| | | | |
2020 | | | | |
Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | (a) | ($9) |
Financial transmission rights | | Purchased power expense | (b) | $28 |
Electricity swaps and options (c) | | Competitive business operating revenues | | ($2) |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
(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.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, 20212022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
| | Instrument | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Registrant | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Registrant |
| | | | | (In Millions) | | | | | | | (In Millions) | | |
| Assets: | Assets: | | Assets: | |
| Natural gas swaps and options | Natural gas swaps and options | | Prepayments and other | | $5.0 | | $0 | | $5.0 | | Entergy Louisiana | Natural gas swaps and options | | Prepayments and other | | $16.1 | | $— | | $16.1 | | Entergy Louisiana |
| Natural gas swaps and options | Natural gas swaps and options | | Other deferred debits and other assets (non-current portion) | | $0.4 | | $0 | | $0.4 | | Entergy Louisiana | Natural gas swaps and options | | Other deferred debits and other assets | | $8.7 | | $— | | $8.7 | | Entergy Louisiana |
| Natural gas swaps | Natural gas swaps | | Prepayments and other | | $9.6 | | $0 | | $9.6 | | Entergy Mississippi | Natural gas swaps | | Prepayments and other | | $20.6 | | $— | | $20.6 | | Entergy Mississippi |
| Natural gas swaps | | Prepayments and other | | $0.1 | | $0 | | $0.1 | | Entergy New Orleans | |
| | | Financial transmission rights | Financial transmission rights | | Prepayments and other | | $4.1 | | ($0.3) | | $3.8 | | Entergy Arkansas | Financial transmission rights | | Prepayments and other | | $4.5 | | ($0.1) | | $4.4 | | Entergy Arkansas |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $4.9 | | ($0.1) | | $4.8 | | Entergy Louisiana | Financial transmission rights | | Prepayments and other | | $5.3 | | ($0.6) | | $4.7 | | Entergy Louisiana |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $2.0 | | $0 | | $2.0 | | Entergy Mississippi | Financial transmission rights | | Prepayments and other | | $0.5 | | $— | | $0.5 | | Entergy Mississippi |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $0.6 | | $0 | | $0.6 | | Entergy New Orleans | Financial transmission rights | | Prepayments and other | | $0.6 | | $— | | $0.6 | | Entergy New Orleans |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $3.8 | | $0 | | $3.8 | | Entergy Texas | Financial transmission rights | | Prepayments and other | | $1.7 | | ($0.2) | | $1.5 | | Entergy Texas |
| | Liabilities: | | Liabilities: | |
| | Natural gas swaps | | Natural gas swaps | | Other current liabilities | | $0.2 | | $— | | $0.2 | | Entergy New Orleans |
|
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 20202021 were as follows:
| | Instrument | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Registrant | Instrument | | Balance Sheet Location | | Gross Fair Value (a) | | Offsetting Position (b) | | Net Fair Value (c) (d) | | Registrant |
| | | | | (In Millions) | | | | | | | (In Millions) | | |
| Assets: | Assets: | | Assets: | |
| Natural gas swaps and options | Natural gas swaps and options | | Prepayments and other | | $0.8 | | $0 | | $0.8 | | Entergy Louisiana | Natural gas swaps and options | | Prepayments and other | | $5.7 | | $— | | $5.7 | | Entergy Louisiana |
| Natural gas swaps and options | Natural gas swaps and options | | Other deferred debits and other assets | | $0.5 | | $0 | | $0.5 | | Entergy Louisiana | Natural gas swaps and options | | Other deferred debits and other assets | | $5.3 | | $— | | $5.3 | | Entergy Louisiana |
| | | Financial transmission rights | Financial transmission rights | | Prepayments and other | | $2.9 | | ($0.2) | | $2.7 | | Entergy Arkansas | Financial transmission rights | | Prepayments and other | | $2.3 | | $— | | $2.3 | | Entergy Arkansas |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $4.3 | | ($0.1) | | $4.2 | | Entergy Louisiana | Financial transmission rights | | Prepayments and other | | $0.6 | | $— | | $0.6 | | Entergy Louisiana |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $0.6 | | $0 | | $0.6 | | Entergy Mississippi | Financial transmission rights | | Prepayments and other | | $0.3 | | $— | | $0.3 | | Entergy Mississippi |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $0.2 | | ($0.1) | | $0.1 | | Entergy New Orleans | Financial transmission rights | | Prepayments and other | | $0.1 | | $— | | $0.1 | | Entergy New Orleans |
| Financial transmission rights | Financial transmission rights | | Prepayments and other | | $1.6 | | $0 | | $1.6 | | Entergy Texas | Financial transmission rights | | Prepayments and other | | $0.8 | | $— | | $0.8 | | Entergy Texas |
| | Liabilities: | Liabilities: | | Liabilities: | |
| | Natural gas swaps and options | | Other current liabilities | | $0.3 | | $0 | | $0.3 | | Entergy Louisiana | |
| Natural gas swaps and options | | Other non-current liabilities | | $1.3 | | $0 | | $1.3 | | Entergy Louisiana | |
| | Natural gas swaps | Natural gas swaps | | Other current liabilities | | $5.0 | | $0 | | $5.0 | | Entergy Mississippi | Natural gas swaps | | Other current liabilities | | $6.7 | | $— | | $6.7 | | Entergy Mississippi |
| Natural gas swaps | Natural gas swaps | | Other current liabilities | | $0.3 | | $0 | | $0.3 | | Entergy New Orleans | Natural gas swaps | | Other current liabilities | | $0.5 | | $— | | $0.5 | | Entergy New Orleans |
(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)As of June 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 $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi $0.2 million for Entergy New Orleans, and $0.5$0.1 million for Entergy Texas.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | | | | | | | |
| | | | | | |
| Instrument | | Income Statement Location | | Amount of gain
(loss) recorded
in the income statement | | Registrant |
| | | | (In Millions) | | |
| 2022 | | | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | | $8.7 | (a) | Entergy Louisiana |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $14.6 | (a) | Entergy Mississippi |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | ($0.2) | (a) | Entergy New Orleans |
| | | | | | |
| Financial transmission rights | | Purchased power expense | | $16.0 | (b) | Entergy Arkansas |
| Financial transmission rights | | Purchased power expense | | $16.1 | (b) | Entergy Louisiana |
| Financial transmission rights | | Purchased power expense | | $2.2 | (b) | Entergy Mississippi |
| Financial transmission rights | | Purchased power expense | | $1.6 | (b) | Entergy New Orleans |
| Financial transmission rights | | Purchased power expense | | $1.0 | (b) | Entergy Texas |
| | | | | | |
| 2021 | | | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | | $4.9 | (a) | Entergy Louisiana |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $13.2 | (a) | Entergy Mississippi |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $0.1 | (a) | Entergy New Orleans |
| | | | | | |
| Financial transmission rights | | Purchased power expense | | $3.4 | (b) | Entergy Arkansas |
| Financial transmission rights | | Purchased power expense | | $5.9 | (b) | Entergy Louisiana |
| Financial transmission rights | | Purchased power expense | | $0.7 | (b) | Entergy Mississippi |
| Financial transmission rights | | Purchased power expense | | $0.8 | (b) | Entergy New Orleans |
| Financial transmission rights | | Purchased power expense | | $4.8 | (b) | Entergy Texas |
| | | | | | |
2020 | | | | | | |
| | | | | | |
Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | ($2.5) | (a) | Entergy Mississippi |
| | | | | | |
| | | | | | |
Financial transmission rights | | Purchased power expense | | $4.8 | (b) | Entergy Arkansas |
Financial transmission rights | | Purchased power expense | | $5.4 | (b) | Entergy Louisiana |
Financial transmission rights | | Purchased power expense | | ($0.4) | (b) | Entergy Mississippi |
Financial transmission rights | | Purchased power expense | | $0.2 | (b) | Entergy New Orleans |
Financial transmission rights | | Purchased power expense | | $5.3 | (b) | Entergy Texas |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | | | | | | | |
| Instrument | | Income Statement Location | | Amount of gain
(loss) recorded
in the income statement | | Registrant |
| | | | (In Millions) | | |
| 2022 | | | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | | $19.8 | (a) | Entergy Louisiana |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $57.4 | (a) | Entergy Mississippi |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $0.9 | (a) | Entergy New Orleans |
| | | | | | |
| Financial transmission rights | | Purchased power | | $23.5 | (b) | Entergy Arkansas |
| Financial transmission rights | | Purchased power | | $25.5 | (b) | Entergy Louisiana |
| Financial transmission rights | | Purchased power | | $3.2 | (b) | Entergy Mississippi |
| Financial transmission rights | | Purchased power | | $2.4 | (b) | Entergy New Orleans |
| Financial transmission rights | | Purchased power | | $4.9 | (b) | Entergy Texas |
| | | | | | |
| 2021 | | | | | | |
| Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | | $6.7 | (a) | Entergy Louisiana |
| Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | $18.3 | (a) | Entergy Mississippi |
| | | | | | |
| | | | | | |
| Financial transmission rights | | Purchased power expense | | $29.5 | (b) | Entergy Arkansas |
| Financial transmission rights | | Purchased power expense | | $18.2 | (b) | Entergy Louisiana |
| Financial transmission rights | | Purchased power expense | | $7.9 | (b) | Entergy Mississippi |
| Financial transmission rights | | Purchased power expense | | $2.0 | (b) | Entergy New Orleans |
| Financial transmission rights | | Purchased power expense | | $82.7 | (b) | Entergy Texas |
| | | | | | |
2020 | | | | | | |
Natural gas swaps and options | | Fuel, fuel-related expenses, and gas purchased for resale | | ($1.3) | (a) | Entergy Louisiana |
Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | ($7.7) | (a) | Entergy Mississippi |
Natural gas swaps | | Fuel, fuel-related expenses, and gas purchased for resale | | ($0.4) | (a) | Entergy New Orleans |
| | | | | | |
Financial transmission rights | | Purchased power expense | | $9.4 | (b) | Entergy Arkansas |
Financial transmission rights | | Purchased power expense | | $10.7 | (b) | Entergy Louisiana |
Financial transmission rights | | Purchased power expense | | ($0.5) | (b) | Entergy Mississippi |
Financial transmission rights | | Purchased power expense | | $0.6 | (b) | Entergy New Orleans |
Financial transmission rights | | Purchased power expense | | $7.6 | (b) | Entergy Texas |
(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Fair Values
The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held byare reflected in future rates and
Entergy Corporation and Subsidiaries
Notes to Financial Statements
the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.
Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.
Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.
The three levels of the fair value hierarchy are:
•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.
•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:
–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.
Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.
•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.
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 Corporation and Subsidiaries
Notes to Financial Statements
The values for power contract assets or liabilities areprior 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 arewere classified as Level 3 assets and liabilities. The valuations of these assets and liabilities arewere performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Corporate Risk Oversight include: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 iswas also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performsperformed 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 arewere based on the estimated amount that the contracts arewere in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equalequaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts includeincluded cash flow hedges that swapswapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values arewere 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 arewere recorded as derivative contract assets or liabilities. For contracts that havehad unit contingent terms, a further discount iswas 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 arewere valued based on a Black Scholes model, and arewere calculated at the end of each month for accounting purposes. Inputs to the valuation includeincluded end of day forward market prices for the period when the transactions will settle,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 arewere reviewed and cancould be adjusted if it iswas determined that there iswas a better representation of fair value.
On a daily basis, the Office of Corporate Risk Oversight calculatescalculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validatesvalidated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences arewere 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 arewere 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 confirmsconfirmed the mark-to-market calculations and preparesprepared price scenarios and credit downgrade scenario analysis. The scenario analysis iswas communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis iswas completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects arewere calculated for this analysis. This analysis iswas 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviewreviews 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that wereare accounted for at fair value on a recurring basis as of June 30, 20212022 and December 31, 2020.2021. 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.
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | Temporary cash investments | | $530 | | | $0 | | | $0 | | | $530 | | Temporary cash investments | | $514 | | | $— | | | $— | | | $514 | |
| | Decommissioning trust funds (a): | Decommissioning trust funds (a): | | Decommissioning trust funds (a): | |
| Equity securities | Equity securities | | 53 | | | 0 | | | 0 | | | 53 | | Equity securities | | 18 | | | — | | | — | | | 18 | |
| Debt securities (b) | Debt securities (b) | | 686 | | | 1,352 | | | 0 | | | 2,038 | | Debt securities (b) | | 598 | | | 1,095 | | | — | | | 1,693 | |
| Common trusts (c) | Common trusts (c) | | 3,148 | | Common trusts (c) | | 2,379 | |
| | Securitization recovery trust account | Securitization recovery trust account | | 33 | | | 0 | | | 0 | | | 33 | | Securitization recovery trust account | | 28 | | | — | | | — | | | 28 | |
| Escrow accounts | Escrow accounts | | 88 | | | 0 | | | 0 | | | 88 | | Escrow accounts | | 331 | | | — | | | — | | | 331 | |
| Gas hedge contracts | Gas hedge contracts | | 15 | | | 0 | | | 0 | | | 15 | | Gas hedge contracts | | 37 | | | 9 | | | — | | | 46 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 15 | | | 15 | | Financial transmission rights | | — | | | — | | | 12 | | | 12 | |
| | $1,405 | | | $1,352 | | | $15 | | | $5,920 | | | $1,526 | | | $1,104 | | | $12 | | | $5,021 | |
|
| | 2020 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2021 | | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | | | | | | | | Assets: | | | | | | | | |
| Temporary cash investments | Temporary cash investments | | $1,630 | | | $0 | | | $0 | | | $1,630 | | Temporary cash investments | | $398 | | | $— | | | $— | | | $398 | |
| Decommissioning trust funds (a): | Decommissioning trust funds (a): | | | | | | | | | Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | Equity securities | | 1,533 | | | 0 | | | 0 | | | 1,533 | | Equity securities | | 132 | | | — | | | — | | | 132 | |
| Debt securities (b) | Debt securities (b) | | 919 | | | 1,698 | | | 0 | | | 2,617 | | Debt securities (b) | | 770 | | | 1,407 | | | — | | | 2,177 | |
| Common trusts (c) | Common trusts (c) | | 3,103 | | Common trusts (c) | | 3,205 | |
| Power contracts | | 0 | | | 0 | | | 38 | | | 38 | | |
| | Securitization recovery trust account | Securitization recovery trust account | | 42 | | | 0 | | | 0 | | | 42 | | Securitization recovery trust account | | 29 | | | — | | | — | | | 29 | |
| Escrow accounts | Escrow accounts | | 148 | | | 0 | | | 0 | | | 148 | | Escrow accounts | | 49 | | | — | | | — | | | 49 | |
| Gas hedge contracts | Gas hedge contracts | | 1 | | | 1 | | | 0 | | | 2 | | Gas hedge contracts | | 6 | | | 5 | | | — | | | 11 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 9 | | | 9 | | Financial transmission rights | | — | | | — | | | 4 | | | 4 | |
| | | | $4,273 | | | $1,699 | | | $47 | | | $9,122 | | | | $1,384 | | | $1,412 | | | $4 | | | $6,005 | |
| Liabilities: | Liabilities: | | | | | | | | | Liabilities: | | | | | | | | |
| | Gas hedge contracts | Gas hedge contracts | | $6 | | | $1 | | | $0 | | | $7 | | 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 valuesvalue presented herein dodoes not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.2 million as of June 30, 2021 and $0.1$0.4 million as of December 31, 20202021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
(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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 20212022 and 2020:
| | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | |
| 2021 | | 2020 |
| Power Contracts | | Financial transmission rights | | Power Contracts | | Financial transmission rights |
| (In Millions) |
| Balance as of April 1, | $0 | | | $4 | | | $85 | | | $4 | |
| Total gains (losses) for the period (a) | | | | | | | |
| Included in earnings | 0 | | | 0 | | | 16 | | | 0 | |
| Included in other comprehensive income | 0 | | | 0 | | | (7) | | | 0 | |
| Included as a regulatory liability/asset | 0 | | | 15 | | | 0 | | | 10 | |
| Issuances of financial transmission rights | 0 | | | 12 | | | 0 | | | 23 | |
| | | | | | | |
| Settlements | 0 | | | (16) | | | (45) | | | (15) | |
| Balance as of June 30, | $0 | | | $15 | | | $49 | | | $22 | |
(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $3 million for the three months ended June 30, 2020. | | | | | | | | | | | | | | | | | | | |
| | 2022 | | | 2021 |
| | | Financial transmission rights | | | | Financial transmission rights |
| | (In Millions) |
| Balance as of April 1, | | | $1 | | | | | $4 | |
| Total gains (losses) for the period | | | | | | | |
| | | | | | | |
| | | | | | | |
| Included as a regulatory liability/asset | | | 32 | | | | | 15 | |
| Issuances of financial transmission rights | | | 16 | | | | | 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, 20212022 and 2020:2021:
| | | 2021 | | 2020 | | | 2022 | | 2021 |
| | Power Contracts | | Financial transmission rights | | Power Contracts | | Financial transmission rights | | | Financial transmission rights | | Power Contracts | | Financial transmission rights |
| | (In Millions) | | | (In Millions) |
| Balance as of January 1, | Balance as of January 1, | $38 | | | $9 | | | $118 | | | $10 | | Balance as of January 1, | | $4 | | | $38 | | | $9 | |
Total gains (losses) for the period (a) | Total gains (losses) for the period (a) | | Total gains (losses) for the period (a) | | |
| Included in earnings | Included in earnings | (2) | | | 3 | | | (2) | | | 0 | | Included in earnings | | — | | | (2) | | | 3 | |
| Included in other comprehensive income | Included in other comprehensive income | 2 | | | 0 | | | 60 | | | 0 | | Included in other comprehensive income | | — | | | 2 | | | — | |
| Included as a regulatory liability/asset | Included as a regulatory liability/asset | 0 | | | 135 | | | 0 | | | 17 | | Included as a regulatory liability/asset | | 52 | | | — | | | 135 | |
| Issuances of financial transmission rights | Issuances of financial transmission rights | 0 | | | 12 | | | 0 | | | 23 | | Issuances of financial transmission rights | | 16 | | | — | | | 12 | |
| | Settlements | Settlements | (38) | | | (144) | | | (127) | | | (28) | | Settlements | | (60) | | | (38) | | | (144) | |
| Balance as of June 30, | Balance as of June 30, | $0 | | | $15 | | | $49 | | | $22 | | Balance as of June 30, | | $12 | | | $— | | | $15 | |
(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $4 million for the six months ended June 30, 2020.
The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.
The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
Significant
Unobservable
Input | | Transaction Type | | Position | | Change to Input | | Effect on
Fair Value |
| Unit contingent discount | | Electricity swaps | | Sell | | Increase (Decrease) | | Decrease (Increase) |
| | | | | | | | |
| | | | | | | | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that wereare accounted for at fair value on a recurring basis as of June 30, 20212022 and December 31, 2020.2021. 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
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | Temporary cash investments | | $16.2 | | | $0 | | | $0 | | | $16.2 | | Temporary cash investments | | $58.2 | | | $— | | | $— | | | $58.2 | |
| Decommissioning trust funds (a): | Decommissioning trust funds (a): | | Decommissioning trust funds (a): | |
| Equity securities | Equity securities | | 12.7 | | | 0 | | | 0 | | | 12.7 | | Equity securities | | 4.1 | | | — | | | — | | | 4.1 | |
| Debt securities | Debt securities | | 99.2 | | | 373.3 | | | 0 | | | 472.5 | | Debt securities | | 131.6 | | | 353.2 | | | — | | | 484.8 | |
| Common trusts (b) | Common trusts (b) | | 891.5 | | Common trusts (b) | | 705.9 | |
| | Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 3.8 | | | 3.8 | | Financial transmission rights | | — | | | — | | | 4.4 | | | 4.4 | |
| | $128.1 | | | $373.3 | | | $3.8 | | | $1,396.7 | | | $193.9 | | | $353.2 | | | $4.4 | | | $1,257.4 | |
| | 2020 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2021 | | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | Temporary cash investments | | $168.0 | | | $0 | | | $0 | | | $168.0 | | Temporary cash investments | | $4.8 | | | $— | | | $— | | | $4.8 | |
| Decommissioning trust funds (a): | Decommissioning trust funds (a): | | Decommissioning trust funds (a): | |
| Equity securities | Equity securities | | 1.3 | | | 0 | | | 0 | | | 1.3 | | Equity securities | | 16.7 | | | — | | | — | | | 16.7 | |
| Debt securities | Debt securities | | 98.2 | | | 349.7 | | | 0 | | | 447.9 | | Debt securities | | 119.5 | | | 406.8 | | | — | | | 526.3 | |
| Common trusts (b) | Common trusts (b) | | 824.7 | | Common trusts (b) | | 895.4 | |
| | Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 2.7 | | | 2.7 | | Financial transmission rights | | — | | | — | | | 2.3 | | | 2.3 | |
| | $267.5 | | | $349.7 | | | $2.7 | | | $1,444.6 | | | $141.0 | | | $406.8 | | | $2.3 | | | $1,445.5 | |
Entergy Louisiana
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | Temporary cash investments | | $206.6 | | | $0 | | | $0 | | | $206.6 | | Temporary cash investments | | $65.7 | | | $— | | | $— | | | $65.7 | |
| | Decommissioning trust funds (a): | Decommissioning trust funds (a): | | Decommissioning trust funds (a): | |
| Equity securities | Equity securities | | 19.6 | | | 0 | | | 0 | | | 19.6 | | Equity securities | | 12.6 | | | — | | | — | | | 12.6 | |
| Debt securities | Debt securities | | 213.2 | | | 484.3 | | | 0 | | | 697.5 | | Debt securities | | 225.0 | | | 508.3 | | | — | | | 733.3 | |
| Common trusts (b) | Common trusts (b) | | 1,268.4 | | Common trusts (b) | | 1,010.6 | |
| Escrow accounts | | Escrow accounts | | 290.1 | | | — | | | — | | | 290.1 | |
| | Securitization recovery trust account | | 3.7 | | | 0 | | | 0 | | | 3.7 | | |
| Gas hedge contracts | Gas hedge contracts | | 5.0 | | | 0.4 | | | 0 | | | 5.4 | | Gas hedge contracts | | 16.1 | | | 8.7 | | | — | | | 24.8 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 4.8 | | | 4.8 | | Financial transmission rights | | — | | | — | | | 4.7 | | | 4.7 | |
| | $448.1 | | | $484.7 | | | $4.8 | | | $2,206.0 | | | $609.5 | | | $517.0 | | | $4.7 | | | $2,141.8 | |
|
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | 2020 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2021 | | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | | | | | | | | Assets: | | | | | | | | |
| Temporary cash investments | Temporary cash investments | | $726.7 | | | $0 | | | $0 | | | $726.7 | | Temporary cash investments | | $18.4 | | | $— | | | $— | | | $18.4 | |
| Decommissioning trust funds (a): | Decommissioning trust funds (a): | | | | | | | | | Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | Equity securities | | 8.7 | | | 0 | | | 0 | | | 8.7 | | Equity securities | | 20.2 | | | — | | | — | | | 20.2 | |
| Debt securities | Debt securities | | 172.4 | | | 459.8 | | | 0 | | | 632.2 | | Debt securities | | 262.6 | | | 531.6 | | | — | | | 794.2 | |
| Common trusts (b) | Common trusts (b) | | 1,153.1 | | Common trusts (b) | | 1,300.1 | |
| | Securitization recovery trust account | | 2.7 | | | 0 | | | 0 | | | 2.7 | | |
| | Gas hedge contracts | Gas hedge contracts | | 0.8 | | | 0.5 | | | 0 | | | 1.3 | | Gas hedge contracts | | 5.7 | | | 5.3 | | | — | | | 11.0 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 4.2 | | | 4.2 | | Financial transmission rights | | — | | | — | | | 0.6 | | | 0.6 | |
| | | | $911.3 | | | $460.3 | | | $4.2 | | | $2,528.9 | | | | $306.9 | | | $536.9 | | | $0.6 | | | $2,144.5 | |
| | Liabilities: | | |
| Gas hedge contracts | | $0.3 | | | $1.3 | | | $0 | | | $1.6 | | |
|
Entergy Mississippi
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| | Temporary cash investments | | Temporary cash investments | | $26.1 | | | $— | | | $— | | | $26.1 | |
| Escrow accounts | Escrow accounts | | $48.9 | | | $0 | | | $0 | | | $48.9 | | Escrow accounts | | 41.1 | | | — | | | — | | | 41.1 | |
| Gas hedge contracts | Gas hedge contracts | | 9.6 | | | 0 | | | 0 | | | 9.6 | | Gas hedge contracts | | 20.6 | | | — | | | — | | | 20.6 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 2.0 | | | 2.0 | | Financial transmission rights | | — | | | — | | | 0.5 | | | 0.5 | |
| | $58.5 | | | $0 | | | $2.0 | | | $60.5 | | | $87.8 | | | $— | | | $0.5 | | | $88.3 | |
|
| | 2020 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2021 | | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| | Temporary cash investments | | Temporary cash investments | | $47.6 | | | $— | | | $— | | | $47.6 | |
| Escrow accounts | Escrow accounts | | $64.6 | | | $0 | | | $0 | | | $64.6 | | Escrow accounts | | 48.9 | | | — | | | — | | | 48.9 | |
| | Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 0.6 | | | 0.6 | | Financial transmission rights | | — | | | — | | | 0.3 | | | 0.3 | |
| | | | $64.6 | | | $0 | | | $0.6 | | | $65.2 | | | | $96.5 | | | $— | | | $0.3 | | | $96.8 | |
| | Liabilities: | Liabilities: | | Liabilities: | |
| Gas hedge contracts | Gas hedge contracts | | $5.0 | | | $0 | | | $0 | | | $5.0 | | Gas hedge contracts | | $6.7 | | | $— | | | $— | | | $6.7 | |
Entergy New Orleans
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | | Temporary cash investments | | $25.7 | | | $— | | | $— | | | $25.7 | |
| Securitization recovery trust account | | Securitization recovery trust account | | 1.7 | | | — | | | — | | | 1.7 | |
| | Securitization recovery trust account | | $2.7 | | | $0 | | | $0 | | | $2.7 | | |
| Escrow accounts | | 38.8 | | | 0 | | | 0 | | | 38.8 | | |
| Gas hedge contracts | | 0.1 | | | 0 | | | 0 | | | 0.1 | | |
| | Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 0.6 | | | 0.6 | | Financial transmission rights | | — | | | — | | | 0.6 | | | 0.6 | |
| | $41.6 | | | $0 | | | $0.6 | | | $42.2 | | | $27.4 | | | $— | | | $0.6 | | | $28.0 | |
| | Liabilities: | | Liabilities: | |
| Gas hedge contracts | | Gas hedge contracts | | $0.2 | | | $— | | | $— | | | $0.2 | |
|
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | 2020 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2021 | | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
| Assets: | Assets: | | Assets: | |
| Temporary cash investments | | Temporary cash investments | | $42.8 | | | $— | | | $— | | | $42.8 | |
| Securitization recovery trust account | | Securitization recovery trust account | | 2.0 | | | — | | | — | | | 2.0 | |
| | Securitization recovery trust account | | $3.4 | | | $0 | | | $0 | | | $3.4 | | |
| Escrow accounts | | 83.0 | | | 0 | | | 0 | | | 83.0 | | |
| | Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 0.1 | | | 0.1 | | Financial transmission rights | | — | | | — | | | 0.1 | | | 0.1 | |
| | $86.4 | | | $0 | | | $0.1 | | | $86.5 | | | $44.8 | | | $— | | | $0.1 | | | $44.9 | |
| | Liabilities: | Liabilities: | | Liabilities: | |
| Gas hedge contracts | Gas hedge contracts | | $0.3 | | | $0 | | | $0 | | | $0.3 | | Gas hedge contracts | | $0.5 | | | $— | | | $— | | | $0.5 | |
Entergy Texas
| | 2021 | | Level 1 | | Level 2 | | Level 3 | | Total | |
| 2022 | | 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | | (In Millions) | | | (In Millions) |
Assets: | Assets: | | Assets: | |
| | Temporary cash investments | | Temporary cash investments | | $14.4 | | | $— | | | $— | | | $14.4 | |
| Securitization recovery trust account | Securitization recovery trust account | | $26.3 | | | $0 | | | $0 | | | $26.3 | | Securitization recovery trust account | | 26.6 | | | — | | | — | | | 26.6 | |
| Financial transmission rights | Financial transmission rights | | 0 | | | 0 | | | 3.8 | | | 3.8 | | Financial transmission rights | | — | | | — | | | 1.5 | | | 1.5 | |
| | $26.3 | | | $0 | | | $3.8 | | | $30.1 | | | $41.0 | | | $— | | | $1.5 | | | $42.5 | |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
Assets: | | | | | | | | |
| Temporary cash investments | | $248.6 | | | $0 | | | $0 | | | $248.6 | |
| Securitization recovery trust account | | 36.2 | | | 0 | | | 0 | | | 36.2 | |
| Financial transmission rights | | 0 | | | 0 | | | 1.6 | | | 1.6 | |
| | $284.8 | | | $0 | | | $1.6 | | | $286.4 | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
System Energy
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
| Assets: | | | | | | | | |
| Temporary cash investments | | $119.1 | | | $0 | | | $0 | | | $119.1 | |
| Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | | 6.0 | | | 0 | | | 0 | | | 6.0 | |
| Debt Securities | | 207.3 | | | 260.5 | | | 0 | | | 467.8 | |
| Common trusts (b) | | | | | | | | 838.7 | |
| | $332.4 | | | $260.5 | | | $0 | | | $1,431.6 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
Assets: | | | | | | | | |
| | | | | | | | |
| Securitization recovery trust account | | $26.6 | | | $— | | | $— | | | $26.6 | |
| Financial transmission rights | | — | | | — | | | 0.8 | | | 0.8 | |
| | $26.6 | | | $— | | | $0.8 | | | $27.4 | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
| Assets: | | | | | | | | |
| Temporary cash investments | | $216.4 | | | $0 | | | $0 | | | $216.4 | |
| Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | | 3.8 | | | 0 | | | 0 | | | 3.8 | |
| Debt securities | | 177.3 | | | 250.4 | | | 0 | | | 427.7 | |
| Common trusts (b) | | | | | | | | 784.4 | |
| | $397.5 | | | $250.4 | | | $0 | | | $1,432.3 | |
(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended 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 rights | 2.8 | | | 4.1 | | | 1.7 | | | 0.4 | | | 2.7 | |
| Gains (losses) included as a regulatory liability/asset | 3.0 | | | 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 | |
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, 2020.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | |
| Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Millions) |
| Balance as of April 1, | $1.1 | | | $1.9 | | | $0.3 | | | $0 | | | $0.3 | |
| Issuances of financial transmission rights | 6.5 | | | 13.2 | | | 1.4 | | | (0.1) | | | 2.4 | |
| Gains (losses) included as a regulatory liability/asset | 3.3 | | | 2.8 | | | (1.0) | | | 0.1 | | | 5.2 | |
| Settlements | (4.8) | | | (5.4) | | | 0.4 | | | (0.2) | | | (5.3) | |
| Balance as of June 30, | $6.1 | | | $12.5 | | | $1.1 | | | ($0.2) | | | $2.6 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six 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 rights | 2.8 | | | 4.1 | | | 1.7 | | | 0.4 | | | 2.7 | |
| Gains (losses) included as a regulatory liability/asset | 27.8 | | | 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 | |
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, 2020.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Millions) |
| Balance as of January 1, | $3.3 | | | $4.5 | | | $0.8 | | | $0.3 | | | $0.9 | |
| Issuances of financial transmission rights | 6.5 | | | 13.2 | | | 1.4 | | | (0.1) | | | 2.4 | |
| Gains (losses) included as a regulatory liability/asset | 5.7 | | | 5.5 | | | (1.6) | | | 0.2 | | | 6.9 | |
| Settlements | (9.4) | | | (10.7) | | | 0.5 | | | (0.6) | | | (7.6) | |
| Balance as of June 30, | $6.1 | | | $12.5 | | | $1.1 | | | ($0.2) | | | $2.6 | |
NOTE 9. DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)
The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.
As discussed in Note 14 to the financial statements herein, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million.
Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in
Entergy Corporation and Subsidiaries
Notes to Financial Statements
the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.
The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 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, 2021 and December 31, 2020 are summarized as follows:
| | | | | | | | | | | | | | | | | | | | |
| | Fair
Value | | Total
Unrealized
Gains | | Total
Unrealized
Losses |
| | (In Millions) |
| 2021 | | | | | | |
| Debt Securities | | $2,038 | | | $92 | | | $8 | |
| | | | | | |
| 2020 | | | | | | |
| Debt Securities | | $2,617 | | | $197 | | | $3 | |
The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 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, 2021 and December 31, 2020:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | June 30, 2021 | | December 31, 2020 |
| | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses |
| | (In Millions) |
| Less than 12 months | | $482 | | | $8 | | | $187 | | | $3 | |
| More than 12 months | | 3 | | | 0 | | | 2 | | | 0 | |
| Total | | $485 | | | $8 | | | $189 | | | $3 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:
| | | | | | | | | | | |
| 2021 | | 2020 |
| (In Millions) |
| Less than 1 year | $0 | | | ($4) | |
| 1 year - 5 years | 455 | | | 672 | |
| 5 years - 10 years | 663 | | | 852 | |
| 10 years - 15 years | 335 | | | 377 | |
| 15 years - 20 years | 117 | | | 144 | |
| 20 years+ | 468 | | | 576 | |
| Total | $2,038 | | | $2,617 | |
During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 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, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 million and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.
The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of June 30, 2021 was $564 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.
Entergy Arkansas
Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows:
| | | | | | | | | | | | | | | | | | | | |
| | Fair
Value | | Total
Unrealized
Gains | | Total
Unrealized
Losses |
| | (In Millions) |
| 2021 | | | | | | |
| Debt Securities | | $472.5 | | | $16.7 | | | $2.7 | |
| | | | | | |
| 2020 | | | | | | |
| Debt Securities | | $447.9 | | | $27.7 | | | $0.3 | |
The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate
Entergy Corporation and Subsidiaries
Notes to Financial Statements
of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years.
The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | June 30, 2021 | | December 31, 2020 |
| | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses |
| | (In Millions) |
| Less than 12 months | | $127.7 | | | $2.7 | | | $29.9 | | | $0.3 | |
| More than 12 months | | 2.0 | | | 0 | | | 0 | | | 0 | |
| Total | | $129.7 | | | $2.7 | | | $29.9 | | | $0.3 | |
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:
| | | | | | | | | | | |
| | 2021 | | 2020 |
| | (In Millions) |
| Less than 1 year | $0 | | | $0 | |
| 1 year - 5 years | 93.6 | | | 113.1 | |
| 5 years - 10 years | 191.6 | | | 189.8 | |
| 10 years - 15 years | 121.5 | | | 81.4 | |
| 15 years - 20 years | 28.8 | | | 28.5 | |
| 20 years+ | 37.0 | | | 35.1 | |
| Total | $472.5 | | | $447.9 | |
During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.
During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2021 and December 31, 2020 are summarized as follows:
| | | | | | | | | | | | | | | | | | | | |
| | Fair
Value | | Total
Unrealized
Gains | | Total
Unrealized
Losses |
| | (In Millions) |
| 2021 | | | | | | |
| Debt Securities | | $697.5 | | | $38.4 | | | $1.9 | |
| | | | | | |
| 2020 | | | | | | |
| Debt Securities | | $632.2 | | | $51.3 | | | $0.5 | |
The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020. As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years.
The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 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, 2021 and December 31, 2020:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | June 30, 2021 | | December 31, 2020 |
| | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses |
| | (In Millions) |
| Less than 12 months | | $124.4 | | | $1.9 | | | $36.4 | | | $0.5 | |
| More than 12 months | | 0.7 | | | 0 | | | 0.8 | | | 0 | |
| Total | | $125.1 | | | $1.9 | | | $37.2 | | | $0.5 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:
| | | | | | | | | | | |
| 2021 | | 2020 |
| (In Millions) |
| Less than 1 year | $0 | | | $0 | |
| 1 year - 5 years | 122.7 | | | 117.0 | |
| 5 years - 10 years | 188.4 | | | 159.4 | |
| 10 years - 15 years | 103.5 | | | 101.2 | |
| 15 years - 20 years | 74.3 | | | 66.9 | |
| 20 years+ | 208.6 | | | 187.7 | |
| Total | $697.5 | | | $632.2 | |
During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.
During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.
System Energy
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
| Assets: | | | | | | | | |
| Temporary cash investments | | $134.6 | | | $— | | | $— | | | $134.6 | |
| Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | | 1.7 | | | — | | | — | | | 1.7 | |
| Debt Securities | | 241.1 | | | 233.1 | | | — | | | 474.2 | |
| Common trusts (b) | | | | | | | | 662.9 | |
| | $377.4 | | | $233.1 | | | $— | | | $1,273.4 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Level 1 | | Level 2 | | Level 3 | | Total |
| | (In Millions) |
| Assets: | | | | | | | | |
| Temporary cash investments | | $89.1 | | | $— | | | $— | | | $89.1 | |
| Decommissioning trust funds (a): | | | | | | | | |
| Equity securities | | 12.9 | | | — | | | — | | | 12.9 | |
| Debt securities | | 273.0 | | | 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 rights | 5.4 | | | 5.3 | | | 0.8 | | | 0.8 | | | 3.9 | |
| Gains (losses) included as a regulatory liability/asset | 14.6 | | | 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 rights | 2.8 | | | 4.1 | | | 1.7 | | | 0.4 | | | 2.7 | |
| Gains (losses) included as a regulatory liability/asset | 3.0 | | | 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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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 rights | 5.4 | | | 5.3 | | | 0.8 | | | 0.8 | | | 3.9 | |
| Gains (losses) included as a regulatory liability/asset | 20.2 | | | 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 rights | 2.8 | | | 4.1 | | | 1.7 | | | 0.4 | | | 2.7 | |
| Gains (losses) included as a regulatory liability/asset | 27.8 | | | 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2022 | | December 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 months | | 123 | | | 23 | | | 99 | | | 4 | |
| Total | | $1,480 | | | $157 | | | $869 | | | $12 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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:
| | | | | | | | | | | |
| 2022 | | 2021 |
| (In Millions) |
| Less than 1 year | $65 | | | $— | |
| 1 year - 5 years | 556 | | | 473 | |
| 5 years - 10 years | 501 | | | 655 | |
| 10 years - 15 years | 120 | | | 389 | |
| 15 years - 20 years | 143 | | | 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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2022 | | December 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 months | | 64.2 | | | 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:
| | | | | | | | | | | |
| | 2022 | | 2021 |
| | (In Millions) |
| Less than 1 year | $30.1 | | | $— | |
| 1 year - 5 years | 157.9 | | | 91.7 | |
| 5 years - 10 years | 201.4 | | | 217.4 | |
| 10 years - 15 years | 43.0 | | | 146.0 | |
| 15 years - 20 years | 34.3 | | | 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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2022 | | December 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 months | | 41.8 | | | 7.5 | | | 42.9 | | | 1.9 | |
| Total | | $570.6 | | | $56.0 | | | $249.8 | | | $3.3 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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:
| | | | | | | | | | | |
| 2022 | | 2021 |
| (In Millions) |
| Less than 1 year | $25.2 | | | $— | |
| 1 year - 5 years | 198.9 | | | 157.8 | |
| 5 years - 10 years | 156.6 | | | 173.0 | |
| 10 years - 15 years | 70.3 | | | 123.0 | |
| 15 years - 20 years | 78.5 | | | 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, 20212022 and December 31, 20202021 are summarized as follows:
| | | Fair
Value | | Total
Unrealized
Gains | | Total
Unrealized
Losses | | Fair
Value | | Total
Unrealized
Gains | | Total
Unrealized
Losses |
| | (In Millions) | | (In Millions) |
| 2022 | | 2022 | |
| Debt Securities | | Debt Securities | | $474.3 | | | $0.2 | | | $49.2 | |
| | 2021 | 2021 | | 2021 | |
| Debt Securities | Debt Securities | | $467.8 | | | $19.4 | | | $2.5 | | Debt Securities | | $524.5 | | | $11.8 | | | $2.9 | |
| | 2020 | | |
| Debt Securities | | $427.7 | | | $30.0 | | | $0.8 | | |
The amortized cost of available-for-sale debt securities was $450.9$523.2 million as of June 30, 20212022 and $398.4$515.6 million as of December 31, 2020.2021. As of June 30, 2021,2022, the available-for-sale debt securities had an average coupon rate of approximately 2.43%2.46%, an average duration of approximately 7.276.61 years, and an average maturity of approximately 10.689.51 years.
The unrealized gains/(losses) recognized during the three and six months ended June 30, 20212022 on equity securities still held as of June 30, 20212022 were $60.6($134.6) million and $103.3($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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 and December 31, 2020:2021:
| | | June 30, 2021 | | December 31, 2020 | | June 30, 2022 | | December 31, 2021 |
| | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses | | Fair
Value | | Gross
Unrealized
Losses |
| | (In Millions) | | (In Millions) |
| Less than 12 months | Less than 12 months | | $149.1 | | | $2.5 | | | $28.9 | | | $0.8 | | Less than 12 months | | $443.6 | | | $45.1 | | | $276.6 | | | $2.3 | |
| More than 12 months | More than 12 months | | 0.1 | | | 0 | | | 0 | | | 0 | | More than 12 months | | 16.7 | | | 4.1 | | | 11.3 | | | 0.6 | |
| Total | Total | | $149.2 | | | $2.5 | | | $28.9 | | | $0.8 | | 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, 20212022 and December 31, 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Millions) | | (In Millions) |
| Less than 1 year | Less than 1 year | $0 | | | ($1.1) | | Less than 1 year | $9.9 | | | $— | |
| 1 year - 5 years | 1 year - 5 years | 144.0 | | | 134.7 | | 1 year - 5 years | 199.2 | | | 156.8 | |
| 5 years - 10 years | 5 years - 10 years | 147.3 | | | 141.5 | | 5 years - 10 years | 142.5 | | | 161.8 | |
| 10 years - 15 years | 10 years - 15 years | 46.3 | | | 31.5 | | 10 years - 15 years | 7.2 | | | 58.6 | |
| 15 years - 20 years | 15 years - 20 years | 2.8 | | | 5.3 | | 15 years - 20 years | 29.8 | | | 1.9 | |
| 20 years+ | 20 years+ | 127.4 | | | 115.8 | | 20 years+ | 85.7 | | | 145.4 | |
| Total | Total | $467.8 | | | $427.7 | | Total | $474.3 | | | $524.5 | |
During the three months ended June 30, 20212022 and 2020,2021, proceeds from the dispositions of available-for-sale securities amounted to $101.6$67.8 million and $73.6$101.6 million, respectively. During the three months ended June 30, 20212022 and 2020,2021, gross gains of $1.9$0.1 million and $5.4$1.9 million, respectively, and gross losses of $0.2$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, 20212022 and 2020,2021, proceeds from the dispositions of available-for-sale securities amounted to $175.7$104 million and $165.6$175.7 million, respectively. During the six months ended June 30, 20212022 and 2020,2021, gross gains of $3.1$0.2 million and $7$3.1 million, respectively, and gross losses of $1.8$5.3 million and $0.4$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, 2021 and2022, Entergy did not record an allowance for expected credit losses related to available-for-sale securities. As of December 31, 2020,2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.2was $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
Entergy Corporation and $0.1 million, respectively.Subsidiaries
Notes to Financial Statements
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 and 2020.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, |
| 2021 | | 2020 | | 2021 | | 2020 |
| (In Millions) |
| Entergy | $14 | | | $15 | | | $54 | | | $45 | |
| Entergy Arkansas | $0 | | | ($1) | | | $8 | | | $12 | |
| Entergy Louisiana | $8 | | | $8 | | | $15 | | | $16 | |
| | | | | | | |
| Entergy New Orleans | $0 | | | $2 | | | $0 | | | $5 | |
| Entergy Texas | $6 | | | $6 | | | $13 | | | $12 | |
| System Entergy | $0 | | | $0 | | | $18 | | | $0 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months
Ended June 30, | | Six Months
Ended June 30, |
| 2022 | | 2021 | | 2022 | | 2021 |
| (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 | |
Valuation AllowanceOther Tax Matters
DuringAs described in Note 2 to the second quarter 2021,financial statements herein, Entergy reducedLouisiana implemented a valuation allowance by $9 million recordedsecuritization 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 deferred tax assetLURC.
Accordingly, the securitization provides for a carryovertax accounting permanent difference resulting in a net reduction of interestincome tax expense because new information indicates that there is sufficient taxableof 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 nature that allowsprovision for carryover utilization.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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 were $254$401 million for Entergy, $35.3$54.8 million for Entergy Arkansas, $95.7$198.7 million for Entergy Louisiana, $26.3$20.9 million for Entergy Mississippi, $3.8$12.7 million for Entergy New Orleans, $45$44.6 million for Entergy Texas, and $16.7$29.2 million for System Energy. Construction expenditures included in accounts payable at December 31, 20202021 were $745$723 million for Entergy, $59.7$35.6 million for Entergy Arkansas, $460.5$507.9 million for Entergy Louisiana, $31.4$26.5 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8$73.1 million for Entergy Texas, and $17.7$23.4 million for System Energy.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 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, 20212022 and in the six months ended June 30, 2020.2021.
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.
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | | | | |
| | 2021 | | 2020 | | | |
| | | | | | | |
| | (In Thousands) | | | |
| Utility: | | | | | | | |
| Residential | | $855,586 | | | $790,869 | | | | |
| Commercial | | 628,703 | | | 526,121 | | | | |
| Industrial | | 756,959 | | | 576,203 | | | | |
| Governmental | | 61,612 | | | 46,959 | | | | |
| Total billed retail | | 2,302,860 | | | 1,940,152 | | | | |
| | | | | | | |
| Sales for resale (a) | | 119,130 | | | 52,761 | | | | |
| Other electric revenues (b) | | 187,078 | | | 168,721 | | | | |
| Revenues from contracts with customers | | 2,609,068 | | | 2,161,634 | | | | |
| Other revenues (c) | | 32,307 | | | 28,923 | | | | |
| Total electric revenues | | 2,641,375 | | | 2,190,557 | | | | |
| | | | | | | |
| Natural gas | | 31,998 | | | 22,495 | | | | |
| | | | | | | |
| Entergy Wholesale Commodities: | | | | | | | |
| Competitive businesses sales from contracts with customers (a) | | 146,680 | | | 175,720 | | | | |
| Other revenues (c) | | 2,017 | | | 24,016 | | | | |
| Total competitive businesses revenues | | 148,697 | | | 199,736 | | | | |
| | | | | | | |
| Total operating revenues | | $2,822,070 | | | $2,412,788 | | | | |
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 | | | |
| | | | | | | |
| | (In Thousands) | | | |
| Utility: | | | | | | | |
| Residential | | $1,035,063 | | | $855,586 | | | | |
| Commercial | | 715,665 | | | 628,703 | | | | |
| Industrial | | 878,194 | | | 756,959 | | | | |
| Governmental | | 67,101 | | | 61,612 | | | | |
| Total billed retail | | 2,696,023 | | | 2,302,860 | | | | |
| | | | | | | |
| Sales for resale (a) | | 249,035 | | | 119,130 | | | | |
| Other electric revenues (b) | | 302,351 | | | 187,078 | | | | |
| Revenues from contracts with customers | | 3,247,409 | | | 2,609,068 | | | | |
| Other revenues (c) | | 10,846 | | | 32,307 | | | | |
| Total electric revenues | | 3,258,255 | | | 2,641,375 | | | | |
| | | | | | | |
| Natural gas | | 48,008 | | | 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 revenues | | 88,933 | | | 148,697 | | | | |
| | | | | | | |
| Total operating revenues | | $3,395,196 | | | $2,822,070 | | | | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
Entergy’s total revenues for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | | 2022 | | 2021 |
| | (In Thousands) | | | (In Thousands) |
| Utility: | Utility: | | | Utility: | |
| Residential | Residential | | $1,822,441 | | | $1,588,897 | | | Residential | | $2,021,085 | | | $1,822,441 | |
| Commercial | Commercial | | 1,201,380 | | | 1,065,061 | | | Commercial | | 1,350,290 | | | 1,201,380 | |
| Industrial | Industrial | | 1,354,610 | | | 1,133,718 | | | Industrial | | 1,621,828 | | | 1,354,610 | |
| Governmental | Governmental | | 118,409 | | | 99,541 | | | Governmental | | 124,395 | | | 118,409 | |
| Total billed retail | Total billed retail | | 4,496,840 | | | 3,887,217 | | | Total billed retail | | 5,117,598 | | | 4,496,840 | |
| | Sales for resale (a) | Sales for resale (a) | | 324,205 | | | 106,487 | | | Sales for resale (a) | | 377,994 | | | 324,205 | |
| Other electric revenues (b) | Other electric revenues (b) | | 267,339 | | | 218,887 | | | Other electric revenues (b) | | 396,231 | | | 267,339 | |
| Revenues from contracts with customers | Revenues from contracts with customers | | 5,088,384 | | | 4,212,591 | | | Revenues from contracts with customers | | 5,891,823 | | | 5,088,384 | |
| Other revenues (c) | Other revenues (c) | | 91,410 | | | 28,605 | | | Other revenues (c) | | 22,208 | | | 91,410 | |
| Total electric revenues | Total electric revenues | | 5,179,794 | | | 4,241,196 | | | Total electric revenues | | 5,914,031 | | | 5,179,794 | |
| | Natural gas | Natural gas | | 90,166 | | | 66,471 | | | Natural gas | | 120,369 | | | 90,166 | |
| | Entergy Wholesale Commodities: | Entergy Wholesale Commodities: | | | Entergy Wholesale Commodities: | |
| Competitive businesses sales from contracts with customers (a) | Competitive businesses sales from contracts with customers (a) | | 378,794 | | | 391,723 | | | Competitive businesses sales from contracts with customers (a) | | 232,534 | | | 378,794 | |
| Other revenues (c) | Other revenues (c) | | 18,153 | | | 140,577 | | | Other revenues (c) | | 6,188 | | | 18,153 | |
| Total competitive businesses revenues | Total competitive businesses revenues | | 396,947 | | | 532,300 | | | Total competitive businesses revenues | | 238,722 | | | 396,947 | |
| | Total operating revenues | Total operating revenues | | $5,666,907 | | | $4,839,967 | | | Total operating revenues | | $6,273,122 | | | $5,666,907 | |
The Registrant Subsidiaries’Utility operating companies’ total revenues for the three months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $171,103 | | | $340,643 | | | $117,461 | | | $60,186 | | | $166,193 | |
| Commercial | | 111,187 | | | 262,351 | | | 101,644 | | | 51,092 | | | 102,429 | |
| Industrial | | 114,284 | | | 475,185 | | | 36,545 | | | 8,028 | | | 122,917 | |
| Governmental | | 4,536 | | | 21,547 | | | 10,873 | | | 18,312 | | | 6,344 | |
| Total billed retail | | 401,110 | | | 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 customers | | 544,069 | | | 1,229,814 | | | 346,963 | | | 159,938 | | | 431,002 | |
| Other revenues (c) | | 6,205 | | | 24,765 | | | 2,077 | | | (177) | | | (568) | |
| Total electric revenues | | 550,274 | | | 1,254,579 | | | 349,040 | | | 159,761 | | | 430,434 | |
| Natural gas | | 0 | | | 13,019 | | | 0 | | | 18,979 | | | 0 | |
| Total operating revenues | | $550,274 | | | $1,267,598 | | | $349,040 | | | $178,740 | | | $430,434 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $199,209 | | | $400,915 | | | $143,705 | | | $80,484 | | | $210,750 | |
| Commercial | | 127,230 | | | 290,063 | | | 118,278 | | | 58,801 | | | 121,293 | |
| Industrial | | 135,809 | | | 536,229 | | | 43,738 | | | 9,216 | | | 153,202 | |
| Governmental | | 5,137 | | | 21,841 | | | 12,611 | | | 20,179 | | | 7,333 | |
| Total billed retail | | 467,385 | | | 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 customers | | 694,959 | | | 1,492,126 | | | 403,181 | | | 222,948 | | | 564,970 | |
| Other revenues (c) | | 1,980 | | | 5,816 | | | 2,278 | | | 1,136 | | | (379) | |
| Total electric revenues | | 696,939 | | | 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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $171,103 | | | $340,643 | | | $117,461 | | | $60,186 | | | $166,193 | |
| Commercial | | 111,187 | | | 262,351 | | | 101,644 | | | 51,092 | | | 102,429 | |
| Industrial | | 114,284 | | | 475,185 | | | 36,545 | | | 8,028 | | | 122,917 | |
| Governmental | | 4,536 | | | 21,547 | | | 10,873 | | | 18,312 | | | 6,344 | |
| Total billed retail | | 401,110 | | | 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 customers | | 544,069 | | | 1,229,814 | | | 346,963 | | | 159,938 | | | 431,002 | |
| Other revenues (c) | | 6,205 | | | 24,765 | | | 2,077 | | | (177) | | | (568) | |
| Total electric revenues | | 550,274 | | | 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 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $171,171 | | | $301,105 | | | $112,361 | | | $53,420 | | | $152,811 | |
| Commercial | | 106,104 | | | 209,119 | | | 89,594 | | | 36,401 | | | 84,904 | |
| Industrial | | 106,254 | | | 335,201 | | | 35,874 | | | 3,066 | | | 95,809 | |
| Governmental | | 4,344 | | | 16,781 | | | 9,798 | | | 10,475 | | | 5,560 | |
| Total billed retail | | 387,873 | | | 862,206 | | | 247,627 | | | 103,362 | | | 339,084 | |
| Sales for resale (a) | | 36,956 | | | 82,698 | | | 18,426 | | | 8,018 | | | 13,187 | |
| Other electric revenues (b) | | 63,537 | | | 53,104 | | | 29,393 | | | 3,999 | | | 20,039 | |
| Revenues from contracts with customers | | 488,366 | | | 998,008 | | | 295,446 | | | 115,379 | | | 372,310 | |
| Other revenues (c) | | 3,401 | | | 3,593 | | | 2,508 | | | 19,520 | | | (116) | |
| Total electric revenues | | 491,767 | | | 1,001,601 | | | 297,954 | | | 134,899 | | | 372,194 | |
| Natural gas | | 0 | | | 10,051 | | | 0 | | | 12,444 | | | 0 | |
| Total operating revenues | | $491,767 | | | $1,011,652 | | | $297,954 | | | $147,343 | | | $372,194 | |
The Registrant Subsidiaries’Utility operating companies’ total revenues for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2021 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $408,284 | | | $676,403 | | | $265,097 | | | $126,613 | | | $346,044 | |
| Commercial | | 217,603 | | | 487,000 | | | 199,580 | | | 98,891 | | | 198,306 | |
| Industrial | | 217,696 | | | 822,194 | | | 70,524 | | | 14,817 | | | 229,379 | |
| Governmental | | 8,791 | | | 40,163 | | | 21,416 | | | 34,692 | | | 13,347 | |
| Total billed retail | | 852,374 | | | 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 customers | | 1,124,999 | | | 2,280,185 | | | 681,318 | | | 298,670 | | | 911,797 | |
| Other revenues (c) | | 8,661 | | | 54,057 | | | 4,341 | | | 239 | | | (1,143) | |
| Total electric revenues | | 1,133,660 | | | 2,334,242 | | | 685,659 | | | 298,909 | | | 910,654 | |
| Natural gas | | 0 | | | 41,000 | | | 0 | | | 49,166 | | | 0 | |
| Total operating revenues | | $1,133,660 | | | $2,375,242 | | | $685,659 | | | $348,075 | | | $910,654 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | (In Thousands) |
| | | | | | | | | | |
| Residential | | $426,995 | | | $754,483 | | | $296,643 | | | $139,141 | | | $403,823 | |
| Commercial | | 240,469 | | | 547,653 | | | 228,939 | | | 104,373 | | | 228,856 | |
| Industrial | | 245,483 | | | 988,182 | | | 82,895 | | | 15,490 | | | 289,778 | |
| Governmental | | 9,598 | | | 40,857 | | | 24,612 | | | 35,211 | | | 14,117 | |
| Total billed retail | | 922,545 | | | 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 customers | | 1,251,104 | | | 2,723,436 | | | 749,916 | | | 376,416 | | | 1,038,061 | |
| Other revenues (c) | | 4,791 | | | 11,743 | | | 4,572 | | | 2,314 | | | (988) | |
| Total electric revenues | | 1,255,895 | | | 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 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | 2020 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas | |
| 2021 | | 2021 | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | | (In Thousands) | | | (In Thousands) |
| | Residential | Residential | | $390,859 | | | $560,965 | | | $239,463 | | | $104,319 | | | $293,291 | | Residential | | $408,284 | | | $676,403 | | | $265,097 | | | $126,613 | | | $346,044 | |
| Commercial | Commercial | | 217,349 | | | 411,365 | | | 186,392 | | | 81,905 | | | 168,050 | | Commercial | | 217,603 | | | 487,000 | | | 199,580 | | | 98,891 | | | 198,306 | |
| Industrial | Industrial | | 207,342 | | | 657,542 | | | 72,264 | | | 10,413 | | | 186,157 | | Industrial | | 217,696 | | | 822,194 | | | 70,524 | | | 14,817 | | | 229,379 | |
| Governmental | Governmental | | 8,374 | | | 33,535 | | | 20,125 | | | 26,326 | | | 11,180 | | Governmental | | 8,791 | | | 40,163 | | | 21,416 | | | 34,692 | | | 13,347 | |
| Total billed retail | Total billed retail | | 823,924 | | | 1,663,407 | | | 518,244 | | | 222,963 | | | 658,678 | | Total billed retail | | 852,374 | | | 2,025,760 | | | 556,617 | | | 275,013 | | | 787,076 | |
| Sales for resale (a) | Sales for resale (a) | | 78,096 | | | 161,228 | | | 32,848 | | | 18,188 | | | 21,815 | | Sales for resale (a) | | 179,834 | | | 154,771 | | | 84,360 | | | 17,506 | | | 93,615 | |
| Other electric revenues (b) | Other electric revenues (b) | | 65,134 | | | 85,113 | | | 35,836 | | | 4,763 | | | 30,742 | | Other electric revenues (b) | | 92,791 | | | 99,654 | | | 40,341 | | | 6,151 | | | 31,106 | |
| Revenues from contracts with customers | Revenues from contracts with customers | | 967,154 | | | 1,909,748 | | | 586,928 | | | 245,914 | | | 711,235 | | Revenues from contracts with customers | | 1,124,999 | | | 2,280,185 | | | 681,318 | | | 298,670 | | | 911,797 | |
| Other revenues (c) | Other revenues (c) | | 6,525 | | | 4,394 | | | 4,948 | | | 12,416 | | | 295 | | Other revenues (c) | | 8,661 | | | 54,057 | | | 4,341 | | | 239 | | | (1,143) | |
| Total electric revenues | Total electric revenues | | 973,679 | | | 1,914,142 | | | 591,876 | | | 258,330 | | | 711,530 | | Total electric revenues | | 1,133,660 | | | 2,334,242 | | | 685,659 | | | 298,909 | | | 910,654 | |
| Natural gas | Natural gas | | 0 | | | 28,157 | | | 0 | | | 38,315 | | | 0 | | Natural gas | | — | | | 41,000 | | | — | | | 49,166 | | | — | |
| Total operating revenues | Total operating revenues | | $973,679 | | | $1,942,299 | | | $591,876 | | | $296,645 | | | $711,530 | | 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 increasesan increase in 2020 in its allowance for doubtful accounts in 2020.accounts. The following table setstables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 20212022 and 2020.2021.
| | | Entergy | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas | | Entergy | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | | (In Millions) | | (In Millions) |
| Balance as of December 31, 2020 | $117.7 | | | $18.3 | | | $45.7 | | | $19.5 | | | $17.4 | | | $16.8 | | |
| Balance as of December 31, 2021 | | Balance as of December 31, 2021 | $68.6 | | | $13.1 | | | $29.2 | | | $7.2 | | | $13.3 | | | $5.8 | |
Provisions | Provisions | 25.9 | | | 5.5 | | | 11.7 | | | 1.7 | | | 4.6 | | | 2.4 | | Provisions | 11.0 | | | 8.2 | | | 0.4 | | | 0.2 | | | 0.9 | | | 1.3 | |
| Write-offs | Write-offs | (39.5) | | | (2.8) | | | (19.5) | | | (8.8) | | | (1.1) | | | (7.3) | | Write-offs | (75.5) | | | (21.8) | | | (29.8) | | | (7.4) | | | (10.4) | | | (6.1) | |
| Recoveries | Recoveries | 5.0 | | | 1.4 | | | 1.9 | | | 1.2 | | | 0.2 | | | 0.3 | | Recoveries | 21.5 | | | 6.7 | | | 7.9 | | | 2.2 | | | 3.1 | | | 1.6 | |
| Balance as of June 30, 2021 | $109.1 | | | $22.4 | | | $39.8 | | | $13.6 | | | $21.1 | | | $12.2 | | |
| Balance as of June 30, 2022 | | Balance as of June 30, 2022 | $25.6 | | | $6.2 | | | $7.7 | | | $2.2 | | | $6.9 | | | $2.6 | |
Entergy Corporation and Subsidiaries
Notes to Financial Statements
| | | Entergy | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas | | Entergy | | Entergy
Arkansas | | Entergy
Louisiana | | Entergy
Mississippi | | Entergy
New
Orleans | | Entergy
Texas |
| | | (In Millions) | | (In Millions) |
| Balance as of December 31, 2019 | $7.4 | | | $1.2 | | | $1.9 | | | $0.6 | | | $3.2 | | | $0.5 | | |
| Balance as of December 31, 2020 | | Balance as of December 31, 2020 | $117.7 | | | $18.3 | | | $45.7 | | | $19.5 | | | $17.4 | | | $16.8 | |
Provisions | Provisions | 38.4 | | | 6.3 | | | 14.1 | | | 7.0 | | | 5.5 | | | 5.5 | | Provisions | 25.9 | | | 5.5 | | | 11.7 | | | 1.7 | | | 4.6 | | | 2.4 | |
| Write-offs | Write-offs | (8.6) | | | (1.8) | | | (3.5) | | | (1.2) | | | (1.0) | | | (1.1) | | Write-offs | (39.5) | | | (2.8) | | | (19.5) | | | (8.8) | | | (1.1) | | | (7.3) | |
| Recoveries | Recoveries | 6.0 | | | 1.6 | | | 2.0 | | | 0.8 | | | 0.7 | | | 0.9 | | Recoveries | 5.0 | | | 1.4 | | | 1.9 | | | 1.2 | | | 0.2 | | | 0.3 | |
| Balance as of June 30, 2020 | $43.2 | | | $7.3 | | | $14.5 | | | $7.2 | | | $8.4 | | | $5.8 | | |
| Balance as of June 30, 2021 | | 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, managementthere 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 Texas)Mississippi)
Acquisitions
Hardin County Peaking FacilitySunflower Solar
In June 2021,November 2018, Entergy Texas purchasedMississippi entered into an agreement for the Hardinpurchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Peaking Facility,Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an existing 147 MW simple-cycle gas-fired peaking power plantindirect 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 Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $67.9 million. The two interdependent transactions were approvedAugust 2019 by consultants retained by the PUCT in April 2021. The purchase priceMississippi Public Utilities Staff and proposing an alternative structure for the Hardin County Peaking Facilitytransaction 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 approximately $36.7 million.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
Entergy Corporation and Subsidiaries
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
Indian Point Energy CenterPalisades
In April 2019,July 2018, Entergy entered into ana purchase and sale agreement with Holtec International to sell directly or indirectly,to a Holtec subsidiary 100% of the equity interests in the subsidiariessubsidiary that own Indianowns Palisades and the Big Rock Point 1, Indian Point 2,Site. In December 2020, Entergy and Indian Point 3, after Indian Point 3 had been shut down and defueled,Holtec submitted a license transfer application to a Holtec International subsidiary. In November 2020 the NRC approvedrequesting approval to transfer the sale of the plantPalisades and Big Rock Point licenses from Entergy to Holtec. Indian Point 3The NRC issued an order approving the application in December 2021. Palisades was shut down in April 2021May 2022 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec.June 2022. The Palisades transaction closed in May 2021.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 licenses,Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel decommissioning liabilities,management and nuclear decommissioning trusts for the three units.plant decommissioning. The transaction resulted in a chargegain of $340$166 million ($268130 million net-of-tax) in the second quarter of 2021.2022. The disposition-date fair value of the nuclear decommissioning trust fundsfund was approximately $2,387$552 million and the disposition-date fair value of the asset retirement obligationsobligation was $1,996approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies and prepaid assets.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
Entergy Corporation and Subsidiaries
Notes to Financial Statements
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, 2021,2022, 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
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, 20212022 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Arkansas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Arkansas were approximately $145 million in February 2021 compared to approximately $40 million in February 2020.See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Arkansas.
In March 2021 the APSC opened an investigation into Arkansas utilities’ preparation, response, operational performance, and communication regarding the February 2021 extreme weather events. Comments from jurisdictional utilities are due in August 2021. In April 2021, the Arkansas Attorney General notified utilities of its intent to conduct an investigation into the fuel costs that were charged during the February 2021 winter storms; specifically, whether there was price gouging by suppliers.
Results of Operations
Net Income
Second Quarter 20212022 Compared to Second Quarter 20202021
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 $3.6$21 million primarily due to lower other income,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.
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Net income increased $44.9 million primarily due to higher volume/weather, the reversal in 2021 of the remaining regulatory liability for the formula rate plan 2019 historical year netting adjustment, and higher retail electric price, partially offset by a higher effective income tax rate, higher other operation and maintenance expenses, and higher depreciation and amortization expenses.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Operating Revenues
Second Quarter 20212022 Compared to Second Quarter 20202021
Following is an analysis of the change in operating revenues comparing the second quarter 20212022 to the second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $491.8550.3 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 40.7117.2 | |
| Volume/weather | 18.1 | |
| |
| Retail electric price | 11.3 | |
| 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.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Total electric energy sales for Entergy Arkansas for the three months ended June 30, 2022 and 2021 are as follows:
| | | | | | | | | | | | | | | | | |
| 2022 | | 2021 | | % Change |
| (GWh) | | |
| Residential | 1,820 | | | 1,758 | | | 4 | |
| Commercial | 1,383 | | | 1,373 | | | 1 | |
| Industrial | 2,135 | | | 2,126 | | | — | |
| Governmental | 56 | | | 55 | | | 2 | |
| Total retail | 5,394 | | | 5,312 | | | 2 | |
| Sales for resale: | | | | | |
| Associated companies | 450 | | | 525 | | | (14) | |
| Non-associated companies | 2,010 | | | 1,700 | | | 18 | |
| Total | 7,854 | | | 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 income | 61.8 | |
| Retail electric price | 9.837.4 | |
| Volume/weather | 15.0 | |
| Return of unprotected excess accumulated deferred income taxes to customers | 8.0 | |
20212022 operating revenues | $550.31,255.9 | |
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 an increaseincreases in formula rate plan rates effective with the first billing cycle of May 2021.2021 and January 2022. See Note 2 to the financial statements hereinin 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 anincreases in commercial and industrial usage, partially offset by the effect of less favorable weather on residential sales. The increase of 396 GWh, or 9%, in billed electricitycommercial usage was primarily due to an increase in commercial usage resulting from reduced impacts fromcustomers and the effect of the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage.2021. The increase in industrial usage iswas primarily due to an increase in demand from expansion projects,existing customers, primarily in the metals industry.wood products and petroleum refining industries.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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 “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic”Note 2 to the financial statements in the Form 10-K for afurther discussion of regulatory activity regarding the COVID-19 pandemic.Tax Cuts and Jobs Act.
BilledTotal electric energy sales for Entergy Arkansas for the threesix months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 1,487 | | | 1,497 | | | (1) | | Residential | 3,912 | | | 3,943 | | | (1) | |
| Commercial | Commercial | 1,260 | | | 1,176 | | | 7 | | Commercial | 2,690 | | | 2,635 | | | 2 | |
| Industrial | Industrial | 2,059 | | | 1,738 | | | 18 | | Industrial | 4,106 | | | 4,073 | | | 1 | |
| Governmental | Governmental | 53 | | | 52 | | | 2 | | Governmental | 111 | | | 110 | | | 1 | |
| Total retail | Total retail | 4,859 | | | 4,463 | | | 9 | | Total retail | 10,819 | | | 10,761 | | | 1 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Associated companies | Associated companies | 525 | | | 308 | | | 70 | | Associated companies | 936 | | | 1,122 | | | (17) | |
| Non-associated companies | Non-associated companies | 1,700 | | | 831 | | | 105 | | Non-associated companies | 3,401 | | | 3,731 | | | (9) | |
| Total | Total | 7,084 | | | 5,602 | | | 26 | | Total | 15,156 | | | 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.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 2020
Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:
| | | | | |
| Amount |
| (In Millions) |
2020 operating revenues | $973.7 | |
Fuel, rider, and other revenues that do not significantly affect net income | 109.0 | |
Volume/weather | 44.0 | |
Retail electric price | 7.0 | |
2021 operating revenues | $1,133.7 | |
Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.
The volume/weather variance is primarily due to an increase of 870 GWh, or 9%, in billed electricity usage, including the effect of more favorable weather on residential sales and increased industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry.
The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of May 2021. See Note 2 to the financial statements herein for further discussion of the 2020 formula rate plan filing.
Billed electric energy sales for Entergy Arkansas for the six months ended June 30, 2021 and 2020 are as follows:
| | | | | | | | | | | | | | | | | |
| 2021 | | 2020 | | % Change |
| (GWh) | | |
| Residential | 3,957 | | | 3,572 | | | 11 | |
| Commercial | 2,525 | | | 2,460 | | | 3 | |
| Industrial | 3,968 | | | 3,549 | | | 12 | |
| Governmental | 107 | | | 106 | | | 1 | |
| Total retail | 10,557 | | | 9,687 | | | 9 | |
| Sales for resale: | | | | | |
| Associated companies | 1,122 | | | 711 | | | 58 | |
| Non-associated companies | 3,731 | | | 1,977 | | | 89 | |
| Total | 15,410 | | | 12,375 | | | 25 | |
See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Other Income Statement Variances
Second Quarter 2021 Compared to Second Quarter 2020
Other operation and maintenance expenses increased primarily due to:
•an increase of $3.4$6.6 million in compensation and benefits costsnon-nuclear generation expenses primarily due to lower healthcare claims activitya higher scope of work, including during plant outages, performed in 20202022 as a result of the COVID-19 pandemic, compared to 2021;
•an increase of $6.5 million in healthcare cost rates, and an increasenuclear generation expenses primarily due to a higher scope of work performed in net periodic pension and other postretirement benefits costs2022 as a result of a decrease in the discount rate usedcompared to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and2021;
•an increase of $3.1 million in non-nuclear generationenergy 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 scope of work performed during plant outagesnuclear insurance refunds received in 2021 as compared2022.
Taxes other than income taxes increased primarily due to 2020.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.service, including the Searcy Solar facility, which was placed in service in December 2021.
Other regulatory charges (credits) - net for the second quarter of 2020 includes regulatory credits of $10.5 million to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing.
Other income decreased primarily due to changes in decommissioning trust fund investment activity.
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Other operation and maintenance expenses increased primarily due to:
•lower nuclear insurance refunds of $5.8 million;
•an increase of $4.9 million in non-nuclear generation expenses due to a higher scope of work performed during plant outages in 2021 as compared to 2020;
•an increase of $3.9 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and
•an increase of $2.2 million in vegetation maintenance costs.
The increase was partially offset by a decrease of $3.9 million in nuclear generation expenses primarily due to lower nuclear labor costs and a lower scope of work performed in 2021 as compared to 2020.
Depreciation and amortization expenses increased primarily due to additions to plant in service.
Other regulatory charges (credits) - net for the six months ended June 30, 2021 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 herein and 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 charges (credits) - netcharge of $2.2 million for the six months ended June 30, 2020 includes regulatory credits2022 to defer the difference between the losses allocated to the tax equity partner under the HLBV method of $22.2 millionaccounting and the earnings/loss that would have been allocated to reflect the amortization of the 2018 historical year netting adjustment reflectedtax equity partner under its respective ownership percentage in the 2019 formula rate plan filing.partnership. See Note 21 to the financial statements in the Form 10-K for
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
discussion of the 2019 formula rate plan filing.
Other income increased primarily due to changes in decommissioning trust fund investment activity.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
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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 NoteNotes 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 24.5% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.
The effective income tax rate was 10.9% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 10 to the financial statements herein and Note 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | | 2021 | | 2020 | | 2022 | | 2021 |
| | | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $192,128 | | | $3,519 | | Cash and cash equivalents at beginning of period | $12,915 | | | $192,128 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 164,633 | | | 287,031 | | Operating activities | 386,522 | | | 164,633 | |
| Investing activities | Investing activities | (326,706) | | | (400,864) | | Investing activities | (376,810) | | | (326,706) | |
| Financing activities | Financing activities | 95,071 | | | 112,887 | | Financing activities | 35,642 | | | 95,071 | |
| Net decrease in cash and cash equivalents | (67,002) | | | (946) | | |
| Net increase (decrease) in cash and cash equivalents | | Net increase (decrease) in cash and cash equivalents | 45,354 | | | (67,002) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $125,126 | | | $2,573 | | Cash and cash equivalents at end of period | $58,269 | | | $125,126 | |
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Operating Activities
Net cash flow provided by operating activities decreased $122.4increased $221.9 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•increased fuel costs as a resulthigher collections from customers;
•the timing of Winter Storm Uri. See “Winter Storm Uri” above for discussionrecovery of the incremental fuel and purchased power costs incurred.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;
•the timinga decrease in spending of collections of receivables from customers,$22 million on nuclear refueling outages in part due to the COVID-19 pandemic;2022;
•$25 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 8 to the financial statements in the Form 10-K for discussiona decrease of the spent nuclear fuel litigation; and
•an increase of $18.9$14.9 million in pension contributions in 2021.2022. 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.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 decreaseincrease was partially offset by the timing of payments to vendors.
Investing Activities
Net cash flow used in investing activities decreased $74.2 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:
•a decrease of $59.5 million in storm spending;
•a decrease of $30.4 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash payments during the nuclear fuel cycle;
•a decrease of $24.3 million in transmission construction expenditures primarily due to a lower scope of work performed in 2021 as compared to 2020; and
•a decrease of $17.2 million in information technology expenditures primarily due to decreased spending on various technology projects.
The decrease was partially offset by:
•$55 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and
•an increase of $28.2 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Arkansas’s distribution system.
Financing Activities
Net cash flow provided by financing activities decreased $17.8 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:
•the repayment, at maturity, of $350 million of 3.75% Series mortgage bonds due February 2021;
•issuance of $100 million of 4.00% Series mortgage bonds in March 2020;
•the repayment, at maturity, of $45 million of 2.375% governmental bonds due January 2021; and
•net repayments of long-term borrowings of $12.2 million in 2021 compared to net long-term borrowings of $8.6 million in 2020 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
The decrease wasInvesting 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 and 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.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.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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,
2021 | | December 31,
2020 | | June 30,
2022 | | December 31,
2021 |
| Debt to capital | Debt to capital | 54.2 | % | | 54.8 | % | Debt to capital | 53.3 | % | | 52.6 | % |
| Effect of subtracting cash | Effect of subtracting cash | (0.8 | %) | | (1.2 | %) | Effect of subtracting cash | (0.3 | %) | | — | % |
| Net debt to net capital | Net debt to net capital | 53.4 | % | | 53.6 | % | Net debt to net capital | 53.0 | % | | 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 they provideit 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:
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2023 | | 2024 |
| | (In Millions) |
| Planned construction and capital investment: | | | | | |
| Generation | $205 | | | $450 | | | $980 | |
| Transmission | 70 | | | 115 | | | 180 | |
| Distribution | 285 | | | 305 | | | 420 | |
| Utility Support | 130 | | | 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.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:
| | | | | | | | | | | | | | | | | | | | |
June 30,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31,
2019 |
| (In Thousands) |
| $8,196 | | $3,110 | | ($25,865) | | ($21,634) |
| | | | | | | | | | | | | | | | | | | | |
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 2026.2027. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 2022.2023. 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, 2021,2022, there were no cash borrowings and no letters of credit were outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2021, a $2.52022, $4.5 million letterin letters of credit waswere outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additionalfurther discussion of the credit facilities.
The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in June 2024.2025. As of June 30, 2021, there2022, $12 million in loans were no loans 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
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
facility for the Entergy Arkansas nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facility.
Searcy Solar Facility
As discussed in the Form 10-K, in April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. A decision on the tax equity partnership is requested by September 2021. Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occurbe in service by the end of 2021.
Walnut Bend Solar Facility
In October 2020,2024. Negotiations with the counter-party are expected to conclude in August 2022, and Entergy Arkansas filed a petition with thehas requested an APSC seeking a finding that the purchase of the 100 MW Walnut Bend Solar Facility is in the public interest. Entergy Arkansas primarily requested cost recovery through the formula rate plan rider. A procedural schedule was established with a paper hearing held in April 2021. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2022.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
2020 Formula Rate Plan Filing
As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021, the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.
20212022 Formula Rate Plan Filing
In July 2021,2022, Entergy Arkansas filed with the APSC its 20212022 formula rate plan filing to set its formula rate for the 20222023 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 20222023 and a netting adjustment for the historical year 2020.2021. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 20222023 projected year is 7.65%7.40% resulting in a revenue deficiency of $89.2$104.8 million. The earned rate of return on common equity for the 20202021 historical year was 7.92%8.38% resulting in a $19.4$15.2 million netting adjustment. The total proposed revenue change for the 20222023 projected year and 20202021 historical year netting adjustment is $108.7$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 $72.6$79.3 million. An order is requested by December 2021.
Energy Cost Recovery Rider
In March 2021,2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decreasean increase from $0.01052$0.00959 per kWh to $0.00959$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 calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate$0.016390 per kWh, which became effective with the first billing cycle in April 20212022 through the normal operation of the tariff.
Opportunity Sales Proceeding
As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit.In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule.In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.
As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. Thethe 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 helddenied the APSC’s motion to dismiss and, in April 2022, issued a hearingscheduling order including a trial date in February 2021 regarding issues addressed2023. 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 pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.motion to intervene. Entergy Arkansas filed a consolidated opposition to both motions.
Net Metering Legislation
SeeAs discussed in the Form 10-K, for discussionan 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
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
lease net metering legislationfacilities, subject to certain leasing arrangements, and subsequent APSC(2) government entities or other entities exempt from state and federal income taxes that enter into a service contract for a net metering proceedings.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 remain pendingremained 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 that court.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 LLCfiled a proposed green tariff designed to help participating customers meet their renewable and Subsidiaries
Management's Financial Discussionsustainability goals and Analysis
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. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021,2022, Entergy Arkansas recordedhad a regulatory asset of $11.2$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.
Entergy Arkansas, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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.
| | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $550,274 | | | $491,767 | | | $1,133,660 | | | $973,679 | | Electric | | $696,939 | | | $550,274 | | | $1,255,895 | | | $1,133,660 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 74,556 | | | 52,692 | | | 200,737 | | | 140,103 | | Fuel, fuel-related expenses, and gas purchased for resale | | 202,795 | | | 74,556 | | | 289,020 | | | 200,737 | |
| Purchased power | Purchased power | | 61,448 | | | 42,171 | | | 131,669 | | | 88,212 | | Purchased power | | 50,209 | | | 61,448 | | | 107,680 | | | 131,669 | |
| Nuclear refueling outage expenses | Nuclear refueling outage expenses | | 13,535 | | | 13,552 | | | 26,182 | | | 29,799 | | Nuclear refueling outage expenses | | 14,210 | | | 13,535 | | | 28,280 | | | 26,182 | |
| Other operation and maintenance | Other operation and maintenance | | 173,098 | | | 164,770 | | | 328,006 | | | 316,627 | | Other operation and maintenance | | 187,319 | | | 173,098 | | | 344,576 | | | 328,006 | |
| Decommissioning | Decommissioning | | 19,280 | | | 18,206 | | | 38,280 | | | 36,147 | | Decommissioning | | 20,428 | | | 19,280 | | | 40,557 | | | 38,280 | |
| Taxes other than income taxes | Taxes other than income taxes | | 30,106 | | | 27,172 | | | 59,849 | | | 58,232 | | Taxes other than income taxes | | 32,072 | | | 30,106 | | | 65,274 | | | 59,849 | |
| Depreciation and amortization | Depreciation and amortization | | 90,276 | | | 84,538 | | | 178,555 | | | 168,059 | | Depreciation and amortization | | 96,548 | | | 90,276 | | | 192,158 | | | 178,555 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | (22,170) | | | (19,283) | | | (59,637) | | | (39,284) | | Other regulatory charges (credits) - net | | (21,518) | | | (22,170) | | | (42,060) | | | (59,637) | |
| TOTAL | TOTAL | | 440,129 | | | 383,818 | | | 903,641 | | | 797,895 | | TOTAL | | 582,063 | | | 440,129 | | | 1,025,485 | | | 903,641 | |
| | OPERATING INCOME | OPERATING INCOME | | 110,145 | | | 107,949 | | | 230,019 | | | 175,784 | | OPERATING INCOME | | 114,876 | | | 110,145 | | | 230,410 | | | 230,019 | |
| | OTHER INCOME (DEDUCTIONS) | OTHER INCOME (DEDUCTIONS) | | OTHER INCOME (DEDUCTIONS) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 3,608 | | | 3,878 | | | 6,601 | | | 6,795 | | Allowance for equity funds used during construction | | 3,920 | | | 3,608 | | | 6,975 | | | 6,601 | |
| Interest and investment income | | (2,739) | | | 8,246 | | | 25,148 | | | 16,184 | | |
| Interest and investment income (loss) | | Interest and investment income (loss) | | 2,840 | | | (2,739) | | | 9,160 | | | 25,148 | |
| Miscellaneous - net | Miscellaneous - net | | (5,372) | | | (6,133) | | | (11,163) | | | (12,569) | | Miscellaneous - net | | (4,892) | | | (5,372) | | | (10,284) | | | (11,163) | |
| TOTAL | TOTAL | | (4,503) | | | 5,991 | | | 20,586 | | | 10,410 | | TOTAL | | 1,868 | | | (4,503) | | | 5,851 | | | 20,586 | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 35,624 | | | 35,969 | | | 69,410 | | | 71,592 | | Interest expense | | 37,452 | | | 35,624 | | | 73,499 | | | 69,410 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (1,572) | | | (1,703) | | | (2,862) | | | (2,984) | | Allowance for borrowed funds used during construction | | (1,558) | | | (1,572) | | | (2,772) | | | (2,862) | |
| TOTAL | TOTAL | | 34,052 | | | 34,266 | | | 66,548 | | | 68,608 | | TOTAL | | 35,894 | | | 34,052 | | | 70,727 | | | 66,548 | |
| | INCOME BEFORE INCOME TAXES | INCOME BEFORE INCOME TAXES | | 71,590 | | | 79,674 | | | 184,057 | | | 117,586 | | INCOME BEFORE INCOME TAXES | | 80,850 | | | 71,590 | | | 165,534 | | | 184,057 | |
| | Income taxes | Income taxes | | 14,997 | | | 19,504 | | | 34,427 | | | 12,821 | | Income taxes | | 17,740 | | | 14,997 | | | 36,857 | | | 34,427 | |
| | NET INCOME | NET INCOME | | $56,593 | | | $60,170 | | | $149,630 | | | $104,765 | | NET INCOME | | 63,110 | | | 56,593 | | | 128,677 | | | 149,630 | |
| | Net loss attributable to noncontrolling interest | | Net loss attributable to noncontrolling interest | | (529) | | | — | | | (1,916) | | | — | |
| | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | $63,639 | | | $56,593 | | | $130,593 | | | $149,630 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | Net income | | $149,630 | | | $104,765 | | Net income | | $128,677 | | | $149,630 | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | Adjustments to reconcile net income to net cash flow provided by operating activities: | | Adjustments to reconcile net income to net cash flow provided by operating activities: | |
| Depreciation, amortization, and decommissioning, including nuclear fuel amortization | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 252,537 | | | 243,126 | | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 268,699 | | | 252,537 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 50,780 | | | 24,970 | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 27,814 | | | 50,780 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Receivables | Receivables | | (86,447) | | | (10,360) | | Receivables | | (95,608) | | | (86,447) | |
| Fuel inventory | Fuel inventory | | 12,996 | | | (12,704) | | Fuel inventory | | 7,316 | | | 12,996 | |
| Accounts payable | Accounts payable | | 27,920 | | | (34,009) | | Accounts payable | | 34,321 | | | 27,920 | |
| Taxes accrued | Taxes accrued | | (6,529) | | | (409) | | Taxes accrued | | 14,824 | | | (6,529) | |
| Interest accrued | Interest accrued | | (2,490) | | | 119 | | Interest accrued | | 1,585 | | | (2,490) | |
| Deferred fuel costs | Deferred fuel costs | | (74,857) | | | 16,322 | | Deferred fuel costs | | (2,384) | | | (74,857) | |
| Other working capital accounts | Other working capital accounts | | (36,703) | | | (23,858) | | Other working capital accounts | | 13,458 | | | (36,703) | |
| Provisions for estimated losses | Provisions for estimated losses | | (6,122) | | | 998 | | Provisions for estimated losses | | (4,119) | | | (6,122) | |
| Other regulatory assets | Other regulatory assets | | 32,837 | | | (26,191) | | Other regulatory assets | | (30,484) | | | 32,837 | |
| Other regulatory liabilities | Other regulatory liabilities | | 17,776 | | | (50,637) | | Other regulatory liabilities | | (267,437) | | | 17,776 | |
| | Pension and other postretirement liabilities | Pension and other postretirement liabilities | | (46,940) | | | (419) | | Pension and other postretirement liabilities | | (31,762) | | | (46,940) | |
| Other assets and liabilities | Other assets and liabilities | | (119,755) | | | 55,318 | | Other assets and liabilities | | 321,622 | | | (119,755) | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 164,633 | | | 287,031 | | Net cash flow provided by operating activities | | 386,522 | | | 164,633 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (322,044) | | | (406,940) | | Construction expenditures | | (351,907) | | | (322,044) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 6,601 | | | 6,795 | | Allowance for equity funds used during construction | | 6,975 | | | 6,601 | |
| Payment for purchase of assets | | 0 | | | (5,988) | | |
| | Nuclear fuel purchases | Nuclear fuel purchases | | (25,466) | | | (57,781) | | Nuclear fuel purchases | | (53,256) | | | (25,466) | |
| Proceeds from sale of nuclear fuel | Proceeds from sale of nuclear fuel | | 16,239 | | | 18,107 | | Proceeds from sale of nuclear fuel | | 37,198 | | | 16,239 | |
| Proceeds from nuclear decommissioning trust fund sales | Proceeds from nuclear decommissioning trust fund sales | | 227,807 | | | 183,474 | | Proceeds from nuclear decommissioning trust fund sales | | 101,428 | | | 227,807 | |
| Investment in nuclear decommissioning trust funds | Investment in nuclear decommissioning trust funds | | (224,757) | | | (194,776) | | Investment in nuclear decommissioning trust funds | | (111,032) | | | (224,757) | |
| Change in money pool receivable - net | | (5,086) | | | 0 | | |
| Changes in securitization account | | 0 | | | 1,244 | | |
| Changes in money pool receivable - net | | Changes in money pool receivable - net | | (6,216) | | | (5,086) | |
| | Litigation proceeds for reimbursement of spent nuclear fuel storage costs | | 0 | | | 55,001 | | |
| | | Net cash flow used in investing activities | Net cash flow used in investing activities | | (326,706) | | | (400,864) | | Net cash flow used in investing activities | | (376,810) | | | (326,706) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | | 694,137 | | | 335,902 | | Proceeds from the issuance of long-term debt | | 223,882 | | | 694,137 | |
| | Retirement of long-term debt | Retirement of long-term debt | | (618,511) | | | (226,366) | | Retirement of long-term debt | | (7,511) | | | (618,511) | |
| | Distributions to noncontrolling interest | | Distributions to noncontrolling interest | | (190) | | | — | |
| | Change in money pool payable - net | | Change in money pool payable - net | | (139,904) | | | — | |
| | Changes in money pool payable - net | | 0 | | | 4,231 | | |
| | Common equity distributions paid | | Common equity distributions paid | | (36,000) | | | — | |
| | Other | Other | | 19,445 | | | (880) | | Other | | (4,635) | | | 19,445 | |
| Net cash flow provided by financing activities | Net cash flow provided by financing activities | | 95,071 | | | 112,887 | | Net cash flow provided by financing activities | | 35,642 | | | 95,071 | |
| | Net decrease in cash and cash equivalents | | (67,002) | | | (946) | | |
| Net increase (decrease) in cash and cash equivalents | | Net increase (decrease) in cash and cash equivalents | | 45,354 | | | (67,002) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 192,128 | | | 3,519 | | Cash and cash equivalents at beginning of period | | 12,915 | | | 192,128 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $125,126 | | | $2,573 | | Cash and cash equivalents at end of period | | $58,269 | | | $125,126 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | |
| Cash paid during the period for: | Cash paid during the period for: | | Cash paid during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $70,700 | | | $69,276 | | Interest - net of amount capitalized | | $70,803 | | | $70,700 | |
| | | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | CURRENT ASSETS | |
| Cash and cash equivalents: | Cash and cash equivalents: | | Cash and cash equivalents: | |
| Cash | Cash | | $108,882 | | | $24,108 | | Cash | | $102 | | | $8,155 | |
| Temporary cash investments | Temporary cash investments | | 16,244 | | | 168,020 | | Temporary cash investments | | 58,167 | | | 4,760 | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 125,126 | | | 192,128 | | Total cash and cash equivalents | | 58,269 | | | 12,915 | |
| | Accounts receivable: | Accounts receivable: | | | | | Accounts receivable: | | | | |
| Customer | Customer | | 208,469 | | | 183,719 | | Customer | | 137,481 | | | 154,412 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | (22,395) | | | (18,334) | | Allowance for doubtful accounts | | (6,206) | | | (13,072) | |
| Associated companies | Associated companies | | 48,646 | | | 34,216 | | Associated companies | | 47,582 | | | 29,587 | |
| Other | Other | | 64,661 | | | 35,845 | | Other | | 113,657 | | | 51,064 | |
| Accrued unbilled revenues | Accrued unbilled revenues | | 136,598 | | | 109,000 | | Accrued unbilled revenues | | 132,964 | | | 101,663 | |
| Total accounts receivable | Total accounts receivable | | 435,979 | | | 344,446 | | Total accounts receivable | | 425,478 | | | 323,654 | |
| | Deferred fuel costs | Deferred fuel costs | | 21,527 | | | 0 | | Deferred fuel costs | | 111,147 | | | 108,862 | |
| Fuel inventory - at average cost | Fuel inventory - at average cost | | 30,815 | | | 43,811 | | Fuel inventory - at average cost | | 43,576 | | | 50,892 | |
| Materials and supplies - at average cost | Materials and supplies - at average cost | | 247,633 | | | 237,640 | | Materials and supplies - at average cost | | 268,184 | | | 247,980 | |
| Deferred nuclear refueling outage costs | Deferred nuclear refueling outage costs | | 46,996 | | | 32,692 | | Deferred nuclear refueling outage costs | | 38,142 | | | 65,318 | |
| | Prepayments and other | Prepayments and other | | 20,228 | | | 13,296 | | Prepayments and other | | 22,011 | | | 14,863 | |
| TOTAL | TOTAL | | 928,304 | | | 864,013 | | TOTAL | | 966,807 | | | 824,484 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | OTHER PROPERTY AND INVESTMENTS | |
| Decommissioning trust funds | Decommissioning trust funds | | 1,376,715 | | | 1,273,921 | | Decommissioning trust funds | | 1,194,815 | | | 1,438,416 | |
| | Other | Other | | 339 | | | 341 | | Other | | 790 | | | 947 | |
| TOTAL | TOTAL | | 1,377,054 | | | 1,274,262 | | TOTAL | | 1,195,605 | | | 1,439,363 | |
| | UTILITY PLANT | UTILITY PLANT | | UTILITY PLANT | |
| Electric | Electric | | 13,067,828 | | | 12,905,322 | | Electric | | 13,740,737 | | | 13,578,297 | |
| | Construction work in progress | Construction work in progress | | 319,379 | | | 234,213 | | Construction work in progress | | 371,705 | | | 241,127 | |
| Nuclear fuel | Nuclear fuel | | 156,819 | | | 163,044 | | Nuclear fuel | | 140,168 | | | 182,055 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 13,544,026 | | | 13,302,579 | | TOTAL UTILITY PLANT | | 14,252,610 | | | 14,001,479 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 5,384,637 | | | 5,255,355 | | Less - accumulated depreciation and amortization | | 5,608,711 | | | 5,472,296 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 8,159,389 | | | 8,047,224 | | UTILITY PLANT - NET | | 8,643,899 | | | 8,529,183 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | DEFERRED DEBITS AND OTHER ASSETS | |
| Regulatory assets: | Regulatory assets: | | Regulatory assets: | |
| | Other regulatory assets | Other regulatory assets | | 1,799,547 | | | 1,832,384 | | Other regulatory assets | | 1,720,162 | | | 1,689,678 | |
| Deferred fuel costs | Deferred fuel costs | | 68,485 | | | 68,220 | | Deferred fuel costs | | 68,850 | | | 68,751 | |
| Other | Other | | 17,292 | | | 14,028 | | Other | | 20,467 | | | 13,660 | |
| TOTAL | TOTAL | | 1,885,324 | | | 1,914,632 | | TOTAL | | 1,809,479 | | | 1,772,089 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $12,350,071 | | | $12,100,131 | | TOTAL ASSETS | | $12,615,790 | | | $12,565,119 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | CURRENT LIABILITIES | |
| Currently maturing long-term debt | Currently maturing long-term debt | | $90,000 | | | $485,000 | | Currently maturing long-term debt | | $250,000 | | | $— | |
| | Accounts payable: | Accounts payable: | | Accounts payable: | |
| Associated companies | Associated companies | | 94,710 | | | 59,448 | | Associated companies | | 67,262 | | | 217,310 | |
| Other | Other | | 183,266 | | | 208,591 | | Other | | 278,178 | | | 190,476 | |
| Customer deposits | Customer deposits | | 92,474 | | | 98,506 | | Customer deposits | | 97,336 | | | 92,511 | |
| Taxes accrued | Taxes accrued | | 75,308 | | | 81,837 | | Taxes accrued | | 104,414 | | | 89,590 | |
| | Interest accrued | Interest accrued | | 20,255 | | | 22,745 | | Interest accrued | | 18,693 | | | 17,108 | |
| Deferred fuel costs | | 0 | | | 53,065 | | |
| | | Other | Other | | 41,682 | | | 40,628 | | Other | | 47,940 | | | 38,901 | |
| TOTAL | TOTAL | | 597,695 | | | 1,049,820 | | TOTAL | | 863,823 | | | 645,896 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | NON-CURRENT LIABILITIES | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 1,346,301 | | | 1,286,123 | | Accumulated deferred income taxes and taxes accrued | | 1,459,515 | | | 1,416,201 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 29,899 | | | 30,500 | | Accumulated deferred investment tax credits | | 28,698 | | | 29,299 | |
| Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 446,059 | | | 467,031 | | Regulatory liability for income taxes - net | | 422,449 | | | 431,655 | |
| Other regulatory liabilities | Other regulatory liabilities | | 725,620 | | | 686,872 | | Other regulatory liabilities | | 485,083 | | | 743,314 | |
| Decommissioning | Decommissioning | | 1,352,440 | | | 1,314,160 | | Decommissioning | | 1,430,967 | | | 1,390,410 | |
| Accumulated provisions | Accumulated provisions | | 64,047 | | | 70,169 | | Accumulated provisions | | 72,965 | | | 77,084 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | 314,639 | | | 361,682 | | Pension and other postretirement liabilities | | 153,960 | | | 185,789 | |
| Long-term debt | Long-term debt | | 3,953,714 | | | 3,482,507 | | Long-term debt | | 3,925,929 | | | 3,958,862 | |
| Other | Other | | 93,858 | | | 75,098 | | Other | | 104,059 | | | 110,754 | |
| TOTAL | TOTAL | | 8,326,577 | | | 7,774,142 | | TOTAL | | 8,083,625 | | | 8,343,368 | |
| | Commitments and Contingencies | Commitments and Contingencies | | Commitments and Contingencies | |
| | | EQUITY | EQUITY | | EQUITY | |
| Member's equity | Member's equity | | 3,425,799 | | | 3,276,169 | | Member's equity | | 3,637,338 | | | 3,542,745 | |
| Noncontrolling interest | | Noncontrolling interest | | 31,004 | | | 33,110 | |
| TOTAL | TOTAL | | 3,425,799 | | | 3,276,169 | | TOTAL | | 3,668,342 | | | 3,575,855 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $12,350,071 | | | $12,100,131 | | TOTAL LIABILITIES AND EQUITY | | $12,615,790 | | | $12,565,119 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | | | | | | | |
ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY |
For the Six Months Ended June 30, 2021 and 2020 |
(Unaudited) |
| | |
| | |
| | Member's Equity |
| | (In Thousands) |
| | |
Balance at December 31, 2019 | | $3,125,937 | |
| | |
Net income | | 44,595 | |
| | |
| | |
| | |
| | |
Balance at March 31, 2020 | | 3,170,532 | |
| | |
Net income | | 60,170 | |
| | |
| | |
| | |
| | |
Balance at June 30, 2020 | | $3,230,702 | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
Balance at December 31, 2020 | | $3,276,169 | |
| | |
Net income | | 93,037 | |
| | |
| | |
| | |
| | |
| | |
| | |
Balance at March 31, 2021 | | 3,369,206 | |
| | |
Net income | | 56,593 | |
| | |
| | |
| | |
| | |
| | |
| | |
Balance at June 30, 2021 | | $3,425,799 | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
See Notes to Financial Statements. | | |
| | | | | | | | | | | | | | | | | |
| ENTERGY ARKANSAS, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | | | | |
| | | | | |
| Noncontrolling Interest | | Member's Equity | | Total |
| (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, 2022 | 31,723 | | | 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. | | | | | |
ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Hurricane Laura, Hurricane Delta, and Hurricane Zeta
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of Entergy Louisiana’s service area. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Louisiana’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Louisiana were approximately $285 million in February 2021 compared to approximately $95 million in February 2020. See Note 2 to the financial statements herein for discussion of the storm cost filings made in 2021 by Entergy Louisiana. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Louisiana.
Results of Operations
Net Income
Second Quarter 20212022 Compared to Second Quarter 20202021
Net income decreased $26.5increased $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, higher depreciation and amortization expenses, and higher interest expense. The decrease was partially offset by higher retail electric price.expenses. See Note 2 to the financial statements herein for further discussion of the securitization.
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 20202021
Net income decreased $49.3increased $157 million primarily due to the $58net effects of Entergy Louisiana’s storm cost securitization, including a $290 million reduction in income tax expense, resulting from an IRS settlement in the first quarter 2020 related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing, which also resulted inpartially offset by a $29$224.4 million ($21165.4 million net-of-tax) regulatory charge to reflect Entergy Louisiana’s agreementits obligation to share the savingsbenefits of the securitization with customers. Also contributing to the decreasenet income increase was higher volume/weather and higher retail price, partially offset by higher other operation and maintenance expenses, higher depreciation and amortization expenses, and higher interest expense. The decrease was partially offset by higher retail electric price and higher volume/weather.expenses. See Note 32 to the financial statements in the Form 10-Kherein for further discussion of the tax settlement.securitization.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Operating Revenues
Second Quarter 20212022 Compared to Second Quarter 20202021
Following is an analysis of the change in operating revenues comparing the second quarter 20212022 to the second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $1,011.71,267.6 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 231.9135.4 | |
| Volume/weather | 56.8 | |
| Storm restoration carrying costs | 37.5 | |
| Retail electric price | 27.3 | |
Volume/weather | (3.3)18.5 | |
| |
20212022 operating revenues | $1,267.61,515.8 | |
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
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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:
•to an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020; and
•an interim increase in formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center.
September 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.
The volume/weather variance is primarily due to the effect of less favorable weather on residential and commercial sales and a decrease in residential usage primarily due to the impact that the COVID-19 pandemic had on prior year usage. The decrease is partially offset by an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage primarily due to increased demand from expansion projects, primarily in the chemicals and transportation industries, and increased demand from existing projects, primarily in the industrial gases and petroleum refining industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
BilledTotal electric energy sales for Entergy Louisiana for the three months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 2,969 | | | 3,239 | | | (8) | | Residential | 3,824 | | | 3,399 | | | 13 | |
| Commercial | Commercial | 2,501 | | | 2,455 | | | 2 | | Commercial | 2,879 | | | 2,641 | | | 9 | |
| Industrial | Industrial | 7,734 | | | 7,427 | | | 4 | | Industrial | 8,148 | | | 7,636 | | | 7 | |
| Governmental | Governmental | 202 | | | 189 | | | 7 | | Governmental | 208 | | | 203 | | | 2 | |
| Total retail | Total retail | 13,406 | | | 13,310 | | | 1 | | Total retail | 15,059 | | | 13,879 | | | 9 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Associated companies | Associated companies | 1,167 | | | 1,407 | | | (17) | | Associated companies | 1,315 | | | 1,167 | | | 13 | |
| Non-associated companies | Non-associated companies | 552 | | | 544 | | | 1 | | Non-associated companies | 467 | | | 552 | | | (15) | |
| Total | Total | 15,125 | | | 15,261 | | | (1) | | Total | 16,841 | | | 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, 20212022 Compared to Six Months Ended June 30, 20202021
Following is an analysis of the change in operating revenues comparing the six months ended June 30, 20212022 to the six months ended June 30, 2020:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $1,942.32,375.2 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 324.3288.8 | |
| Volume/weather | 44.5 | |
| Storm restoration carrying costs | 37.5 | |
| Retail electric price | 75.4 | |
Volume/weather | 33.235.8 | |
| |
20212022 operating revenues | $2,375.22,781.8 | |
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.
The retail electric price variance is primarily due to:
•an interim increase in formula rate plan revenues effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station;
•an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020; and
•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center.
See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales increased residential usage, and an increase in commercial and industrial usage, during the unbilled sales period. The increase is partially offset by a decrease in commercial and industrialweather-adjusted residential usage. The decreaseincrease in industrial usage iswas primarily due to decreased demand from mid to small customers and existing customers in the chemicals and petroleum refining industries as a result of the COVID-19 pandemic and temporary plant shutdowns and operational issues. The decrease in industrial usage is partially offset by 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 industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS -and pulp and paper industries as a result of prior year temporary plant shutdowns. The COVID-19 Pandemicincreased 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 afurther discussion of the COVID-19 pandemic.formula rate plan proceedings.
BilledTotal electric energy sales for Entergy Louisiana for the six months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 6,469 | | | 6,214 | | | 4 | | Residential | 6,893 | | | 6,596 | | | 5 | |
| Commercial | Commercial | 4,910 | | | 4,914 | | | — | | Commercial | 5,300 | | | 5,036 | | | 5 | |
| Industrial | Industrial | 14,744 | | | 14,877 | | | (1) | | Industrial | 15,754 | | | 14,844 | | | 6 | |
| Governmental | Governmental | 398 | | | 388 | | | 3 | | Governmental | 399 | | | 399 | | | — | |
| Total retail | Total retail | 26,521 | | | 26,393 | | | — | | Total retail | 28,346 | | | 26,875 | | | 5 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Associated companies | Associated companies | 2,126 | | | 2,748 | | | (23) | | Associated companies | 2,656 | | | 2,126 | | | 25 | |
| Non-associated companies | Non-associated companies | 938 | | | 1,001 | | | (6) | | Non-associated companies | 1,323 | | | 938 | | | 41 | |
| Total | Total | 29,585 | | | 30,142 | | | (2) | | Total | 32,325 | | | 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 20212022 Compared to Second Quarter 2020
Other operation and maintenance expenses increased primarily due to:
•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $7.7 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;
•an increase of $6.3 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;
•an increase of $5.1 million in energy efficiency costs due to the timing of recovery from customers;
•an increase of $4.8 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020 and higher expenses associated with plants placed in service, including the Washington Parish Energy Center, purchased in November 2020;
•an increase of $4.4 million in distribution operations expenses primarily due to higher distribution reliability costs;
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
•an increase of $2.3 million in information technology costs primarily due to higher contract costs and higher costs associated with system maintenance;
•an increase of $2.1 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives;
•an increase of $2.1 million in vegetation maintenance costs; and
•several individually insignificant items.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including Washington Parish Energy Center, which was placed in service in November 2020.
Interest expense increased primarily due to:
•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020; and
•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021.
The increase was partially offset by the repayment of $250 million of 3.95% Series mortgage bonds in October 2020, the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and the repayment of $200 million of 4.8% Series mortgage bonds in May 2021.
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Other operation and maintenance expenses increased primarily due to:
•an increase of $11.2$7.3 million in nuclear generationpower delivery expenses primarily due to higher nuclear laborreliability costs and higher safety and training costs, partially offset by a higher scopedecrease in meter reading expenses as a result of work performed in 2021 as compared to 2020;the deployment of advanced metering systems;
•an increase of $8.7$3.9 million in compensation and benefits costsbad debt expense primarily due to lower healthcare claims activitythe deferral in 2020 as a result2021 of bad debt expense resulting from the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities.pandemic. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 62 to the financial statements herein and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;
•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $7.7 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;
•an increase of $6.3 million in non-nuclear generation expenses due to higher expensesregulatory activity associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020, and the Washington Parish Energy Center, purchased in November 2020;COVID-19 pandemic;
•an increase of $5.5 million in distribution operations expenses primarily due to higher distribution reliability costs and an increase in vegetation maintenance costs;
•an increase of $5.2 million in energy efficiency costs due to the timing of recovery from customers;
•a decrease of $4.2 million in nuclear insurance refunds; and
•several individually insignificant items.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
•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. Ad valorem taxes increased primarily due toresulting from higher assessments including additions to plantand increases in service.franchise taxes.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station, which was placed in service in March 2020, and the Washington Parish Energy Center, which was placed in service in November 2020.service.
Other regulatory charges (credits) - net includes a regulatory chargescharge of $29$224 million, recorded in firstsecond quarter 2020 due2022, to a settlement withreflect Entergy Louisiana’s obligation to provide credits to its customers in recognition of obligations related to an LPSC ancillary order issued in the IRS relatedHurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida securitization regulatory proceeding. See Note 2 to the uncertain tax position regarding Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 3 in the Form 10-Kfinancial statements herein for further discussion of the settlement and savings obligation.securitization.
Other income decreased primarily due to a decrease$31.6 million charge for the LURC’s 1% beneficial interest in the allowancestorm 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 equity funds used during constructiondiscussion 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 constructionreliability 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 progress2022 as compared to prior year, partially offset by lower spending in 2020,2022 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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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 Lake Charles Power Station project.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 issuance of $350 million of 2.90% Series mortgage bonds in March 2020;
•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;
•the issuanceissuances 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
•a decreasethe issuance of $1 billion of 0.95% Series mortgage bonds in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.October 2021.
The increase was partially offset by the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and $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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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.
The effective income tax rate was 17.4% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was 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.
The effective income tax rate was (4.1%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
compensation, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, book and tax differences related to the allowance for equity funds used during construction, 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 for discussion of the IRS settlement. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $728,020 | | | $2,006 | | Cash and cash equivalents at beginning of period | $18,573 | | | $728,020 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 519,407 | | | 726,789 | | Operating activities | 206,713 | | | 519,407 | |
| Investing activities | Investing activities | (1,836,723) | | | (732,085) | | Investing activities | (3,653,859) | | | (1,836,723) | |
| Financing activities | Financing activities | 796,170 | | | 467,025 | | Financing activities | 3,494,744 | | | 796,170 | |
| Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | (521,146) | | | 461,729 | | Net increase (decrease) in cash and cash equivalents | 47,598 | | | (521,146) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $206,874 | | | $463,735 | | Cash and cash equivalents at end of period | $66,171 | | | $206,874 | |
Operating Activities
Net cash flow provided by operating activities decreased $207.4by $312.7 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•an increase of approximately $109.3 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;
•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred.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;
•an increase of $35.1approximately $107 million in storm spending, on nuclear refueling outages;
•income tax refunds of $20.7 millionprimarily due to Hurricane Ida restoration efforts in 2020. Entergy Louisiana had income tax refunds2022, partially offset by Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts in 2020 as a result of a refund of an overpayment on a prior year state income tax return;2021; and
•an increasethe timing of $20.7payments to vendors.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
The decrease was partially offset by higher collections from customers and a decrease of $26 million in pension contributions in 2021.2022. 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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Investing Activities
Net cash flow used in investing activities increased $1,104.6$1,817.1 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•an increase of $921.6 million in storm spendinginvestments in 2021, primarilyaffiliates due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts.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 “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” aboveNote 2 to the financial statements herein for a discussion of storm restoration efforts;the securitization;
•an increase of $74.4$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;
•an increase of $73.7 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Louisiana’s distribution system;
•$39.2 million in net receipts from storm reserve escrow accounts in 2020; and
•an increase of $28.1 million in nuclear construction expenditures primarily due to increased spending on various projects in 2021.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 increase was partially offset by a decrease of $55.4 million in non-nuclear generation construction expenditures duemoney pool is an inter-company borrowing arrangement designed to higher spending in 2020 onreduce the Lake Charles Power Station.Utility subsidiaries’ need for external short-term borrowings.
Financing Activities
Net cash flow provided by financing activities increased $329.1$2,698.6 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•proceeds from securitization of $3.2 billion received by the storm trust;
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
•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, as compared to 2021;
•the issuancesrepayment in May 2022 of $350$435 million, a portion of 2.90%the outstanding principal, of 0.62% Series mortgage bonds and $300due November 2023;
•net repayments of $125 million of 4.20% Series mortgage bonds, each in March 2020;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 compared to net repayments of long-term borrowings of $59.9 million in 2020 on the nuclear fuel company variable interest entities’ credit facilities;
•money pool activity; and
•the payment of $16.5$125 million in common equity distributions in 2020 primarily2022 to maintainreturn to Entergy Louisiana’sCorporation the $125 million capital structure.
The decrease was partially offset by the repayment of $200 million of 4.80% Series mortgage bondscontribution received in MayDecember 2021 and the repayment of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notesto assist in February 2021.
Decreases in Entergy Louisiana’s payable to the money pool are a use of cash flow, and Entergy Louisiana’s payable to the money pool decreased by $82.8 millionpaying for the six months ended June 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short term borrowings.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 increasedecrease in the debt to capital ratio for Entergy Louisiana is primarily due to the issuance of $1$1.0 billion of mortgage bondscapital contribution received indirectly from Entergy Corporation in March 2021.May 2022.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
| | | | | | | | | | | |
| June 30,
2021 | | December 31,
2020 |
| Debt to capital | 55.9 | % | | 54.8 | % |
| Effect of excluding securitization bonds | 0.0 | % | | 0.0 | % |
| Debt to capital, excluding securitization bonds (a) | 55.9 | % | | 54.8 | % |
| Effect of subtracting cash | (0.5 | %) | | (2.1 | %) |
| Net debt to net capital, excluding securitization bonds (a) | 55.4 | % | | 52.7 | % |
(a)Calculation excludes the securitization bonds, which are non-recourse to Entergy Louisiana. | | | | | | | | | | | |
| June 30,
2022 | | December 31,
2021 |
| Debt to capital | 52.1 | % | | 57.2 | % |
| | | |
| | | |
| Effect of subtracting cash | (0.2 | %) | | 0.0 | % |
| Net debt to net capital | 51.9 | % | | 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 common equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the debt to capital ratios excluding securitization bondsratio in analyzing its financial condition and believes they provideit provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because the securitization bonds are non-recourse to Entergy Louisiana, as more fully described in Note 5 to the financial statements in the Form 10-K.condition. Entergy Louisiana also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because net debt indicates Entergy Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.
Uses and Sources of Capital
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Louisiana’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Following are the amounts of Entergy Louisiana’s planned construction and other capital investments.
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2023 | | 2024 |
| | (In Millions) |
| Planned construction and capital investment: | | | | | |
| Generation | $395 | | | $380 | | | $580 | |
| Transmission | 545 | | | 380 | | | 520 | |
| Distribution | 475 | | | 460 | | | 550 | |
| Utility Support | 200 | | | 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 or (payables to) the money pool were as follows:
| | | | | | | | | | | | | | | | | | | | |
June 30,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31,
2019 |
| (In Thousands) |
| $103,651 | | $13,426 | | $87,635 | | ($82,826) |
| | | | | | | | | | | | | | | | | | | | |
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 2026.2027. 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, 2021,2022, 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, 2021, $7.82022, $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 2024.2025. As of June 30, 2021, $64.62022, $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, 2021, $62.12022, $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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
State2021 Solar Certification and Local Rate Regulation and Fuel-Cost Recovery
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS –State and Local Rate Regulation and Fuel Cost Recovery”in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.
Retail Rates - Electric
2017 Formula Rate Plan Filing
As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.
Request for Extension and Modification of Formula Rate PlanGeaux Green Option
As discussed in the Form 10-K, in May 2020,November 2021, Entergy Louisiana filed an application with the LPSC itsseeking 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 authoritythe resources complies with applicable LPSC orders. LPSC staff and LEUG’s witnesses made recommendations to extend its formula rate plan. The parties reached a settlement in April 2021 regardingmodify the proposed Rider GGO and Entergy Louisiana’s proposed FRP extension.rate relief. In May 2021April 2022, LPSC staff and LEUG filed cross-answering testimony concerning the LPSC approvedother party’s proposed modifications to Rider GGO and the uncontested settlement. Key terms of the settlement include:proposed rate recovery. Entergy Louisiana filed rebuttal testimony in June 2022. Settlement talks are ongoing, and a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increasehearing is set for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.
2020 Formula Rate Plan Filingmid-August 2022.
Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane IdaIn June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Storm Cost Filings
Inn August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.
In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.
In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incrementaladditional outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.
In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by thethese storms are currentlywere estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seekingsought an LPSC determination that $2.11 billion was prudently incurred and, therefore, iswas eligible for recovery from customers. Additionally, Entergy Louisiana is requestingrequested that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million iswas appropriate. In June 2021 a procedural schedule was established with a hearing in January 2022. 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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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 requested authorizationis 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 issuanceLPSC approved financing of system restoration bonds in one or more series in an aggregate principal amount of $2.18a $1 billion which includes the costs of re-establishing and funding a storm damage escrow account carryingfrom which funds were withdrawn to finance costs and unamortized debt costs on interimassociated with Hurricane Ida restoration. In June 2022, Entergy Louisiana supplemented the application with a request regarding the financing and issuancerecovery 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
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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
InAs 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. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery throughIn April 2022 the LPSC staff issued a draft audit report regarding Entergy Louisiana’s fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
the prudence ofcharges in February 2021 fuel costs incurredthat did not recommend any financial disallowances, but included several prospective recommendations. Responsive testimony was filed by all LPSC-jurisdictional utilities. At its June 2021 meeting,one intervenor and the LPSC approvedparties agreed to suspend any procedural schedule and move toward settlement discussions to close the hiring of consultants to assist its staff in this review. Discovery is ongoing.matter.
In March 2021May 2022 the LPSC staff provided notice of anissued a draft audit ofreport regarding Entergy Louisiana’s purchased gas adjustment clause filings coveringcharges 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 period January 2018 through December 2020.matter.
The audit includes a review
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 reasonableness of charges flowed through Entergy Louisiana’s purchased gasfuel adjustment clause for that period.No audit report has been filed.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. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020.In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021,2022, Entergy Louisiana recordedhad a regulatory asset of $54.7$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.
Entergy Louisiana, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Nuclear Matters
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.
Environmental Risks
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.
Critical Accounting Estimates
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy 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.
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $1,254,579 | | | $1,001,601 | | | $2,334,242 | | | $1,914,142 | | Electric | | $1,497,942 | | | $1,254,579 | | | $2,735,179 | | | $2,334,242 | |
| Natural gas | Natural gas | | 13,019 | | | 10,051 | | | 41,000 | | | 28,157 | | Natural gas | | 17,843 | | | 13,019 | | | 46,578 | | | 41,000 | |
| TOTAL | TOTAL | | 1,267,598 | | | 1,011,652 | | | 2,375,242 | | | 1,942,299 | | TOTAL | | 1,515,785 | | | 1,267,598 | | | 2,781,757 | | | 2,375,242 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 355,362 | | | 161,610 | | | 500,596 | | | 306,102 | | Fuel, fuel-related expenses, and gas purchased for resale | | 253,505 | | | 355,362 | | | 615,579 | | | 500,596 | |
| Purchased power | Purchased power | | 186,596 | | | 153,786 | | | 396,557 | | | 314,529 | | Purchased power | | 420,549 | | | 186,596 | | | 596,746 | | | 396,557 | |
| Nuclear refueling outage expenses | Nuclear refueling outage expenses | | 12,193 | | | 13,654 | | | 25,475 | | | 27,284 | | Nuclear refueling outage expenses | | 10,029 | | | 12,193 | | | 21,976 | | | 25,475 | |
| Other operation and maintenance | Other operation and maintenance | | 275,599 | | | 226,216 | | | 513,082 | | | 448,874 | | Other operation and maintenance | | 293,746 | | | 275,599 | | | 547,747 | | | 513,082 | |
| Decommissioning | Decommissioning | | 17,035 | | | 16,203 | | | 33,858 | | | 32,204 | | Decommissioning | | 17,911 | | | 17,035 | | | 35,599 | | | 33,858 | |
| Taxes other than income taxes | Taxes other than income taxes | | 51,968 | | | 48,718 | | | 104,452 | | | 98,795 | | Taxes other than income taxes | | 58,566 | | | 51,968 | | | 120,181 | | | 104,452 | |
| Depreciation and amortization | Depreciation and amortization | | 163,061 | | | 154,255 | | | 323,874 | | | 299,390 | | Depreciation and amortization | | 171,719 | | | 163,061 | | | 340,802 | | | 323,874 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | (21,617) | | | (19,202) | | | 9,480 | | | (8,070) | | Other regulatory charges (credits) - net | | 203,461 | | | (21,617) | | | 182,564 | | | 9,480 | |
| TOTAL | TOTAL | | 1,040,197 | | | 755,240 | | | 1,907,374 | | | 1,519,108 | | TOTAL | | 1,429,486 | | | 1,040,197 | | | 2,461,194 | | | 1,907,374 | |
| | OPERATING INCOME | OPERATING INCOME | | 227,401 | | | 256,412 | | | 467,868 | | | 423,191 | | OPERATING INCOME | | 86,299 | | | 227,401 | | | 320,563 | | | 467,868 | |
| | OTHER INCOME | OTHER INCOME | | OTHER INCOME | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 6,835 | | | 6,055 | | | 12,936 | | | 20,942 | | Allowance for equity funds used during construction | | 2,859 | | | 6,835 | | | 9,585 | | | 12,936 | |
| Interest and investment income | Interest and investment income | | 59,457 | | | 93,807 | | | 131,972 | | | 74,138 | | Interest and investment income | | (68,382) | | | 27,559 | | | (84,380) | | | 68,175 | |
| Interest and investment income - affiliated | | Interest and investment income - affiliated | | 43,203 | | | 31,898 | | | 75,101 | | | 63,797 | |
| Miscellaneous - net | Miscellaneous - net | | (36,033) | | | (66,811) | | | (70,671) | | | (17,210) | | Miscellaneous - net | | 36,986 | | | (36,033) | | | 52,503 | | | (70,671) | |
| TOTAL | TOTAL | | 30,259 | | | 33,051 | | | 74,237 | | | 77,870 | | TOTAL | | 14,666 | | | 30,259 | | | 52,809 | | | 74,237 | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 90,630 | | | 86,296 | | | 173,436 | | | 165,813 | | Interest expense | | 92,755 | | | 90,630 | | | 186,539 | | | 173,436 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (3,068) | | | (3,202) | | | (5,827) | | | (10,334) | | Allowance for borrowed funds used during construction | | (1,218) | | | (3,068) | | | (4,244) | | | (5,827) | |
| TOTAL | TOTAL | | 87,562 | | | 83,094 | | | 167,609 | | | 155,479 | | TOTAL | | 91,537 | | | 87,562 | | | 182,295 | | | 167,609 | |
| | INCOME BEFORE INCOME TAXES | INCOME BEFORE INCOME TAXES | | 170,098 | | | 206,369 | | | 374,496 | | | 345,582 | | INCOME BEFORE INCOME TAXES | | 9,428 | | | 170,098 | | | 191,077 | | | 374,496 | |
| | Income taxes | Income taxes | | 26,171 | | | 35,910 | | | 63,943 | | | (14,273) | | Income taxes | | (307,231) | | | 26,171 | | | (276,442) | | | 63,943 | |
| | NET INCOME | NET INCOME | | $143,927 | | | $170,459 | | | $310,553 | | | $359,855 | | NET INCOME | | 316,659 | | | 143,927 | | | 467,519 | | | 310,553 | |
| | Noncontrolling interest | | Noncontrolling interest | | 258 | | | — | | | 258 | | | — | |
| | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | $316,401 | | | $143,927 | | | $467,261 | | | $310,553 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME | CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME | CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| | Net Income | Net Income | $143,927 | | | $170,459 | | | $310,553 | | | $359,855 | | Net Income | $316,659 | | | $143,927 | | | $467,519 | | | $310,553 | |
| | Other comprehensive income (loss) | Other comprehensive income (loss) | | Other comprehensive income (loss) | |
| Pension and other postretirement liabilities (net of tax expense (benefit) of $208, ($334), $64, and $3,006) | 588 | | | (945) | | | 181 | | | 8,522 | | |
| Pension and other postretirement liabilities (net of tax expense (benefit) of ($181), $208, ($407), and $64) | | 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) | Other comprehensive income (loss) | 588 | | | (945) | | | 181 | | | 8,522 | | Other comprehensive income (loss) | (491) | | | 588 | | | (1,104) | | | 181 | |
| | Comprehensive Income | Comprehensive Income | $144,515 | | | $169,514 | | | $310,734 | | | $368,377 | | Comprehensive Income | 316,168 | | | 144,515 | | | 466,415 | | | 310,734 | |
| Noncontrolling interest | | Noncontrolling interest | 258 | | | — | | | 258 | | | — | |
| Comprehensive Income Applicable to Member’s Equity | | Comprehensive Income Applicable to Member’s Equity | $315,910 | | | $144,515 | | | $466,157 | | | $310,734 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | Net income | | $310,553 | | | $359,855 | | Net income | | $467,519 | | | $310,553 | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | Adjustments to reconcile net income to net cash flow provided by operating activities: | | Adjustments to reconcile net income to net cash flow provided by operating activities: | |
| Depreciation, amortization, and decommissioning, including nuclear fuel amortization | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 402,106 | | | 392,286 | | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 414,975 | | | 402,106 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 90,537 | | | (1,353) | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | (198,525) | | | 90,537 | |
| Changes in working capital: | Changes in working capital: | | Changes in working capital: | |
| Receivables | Receivables | | (66,281) | | | (38,175) | | Receivables | | (114,357) | | | (66,281) | |
| Fuel inventory | Fuel inventory | | (1,240) | | | (2,233) | | Fuel inventory | | (183) | | | (1,240) | |
| Accounts payable | Accounts payable | | 25,685 | | | (37,576) | | Accounts payable | | (20,380) | | | 25,685 | |
| Prepaid taxes and taxes accrued | | 54,850 | | | 91,662 | | |
| Taxes accrued | | Taxes accrued | | (1,686) | | | 54,850 | |
| Interest accrued | Interest accrued | | 2,162 | | | 3,689 | | Interest accrued | | (3,263) | | | 2,162 | |
| Deferred fuel costs | Deferred fuel costs | | (96,429) | | | (763) | | Deferred fuel costs | | (367,321) | | | (96,429) | |
| Other working capital accounts | Other working capital accounts | | (36,605) | | | (13,069) | | Other working capital accounts | | (107,409) | | | (36,605) | |
| Changes in provisions for estimated losses | Changes in provisions for estimated losses | | (291) | | | (38,621) | | Changes in provisions for estimated losses | | 294,067 | | | (291) | |
| Changes in other regulatory assets | Changes in other regulatory assets | | (124,939) | | | 48,536 | | Changes in other regulatory assets | | 859,908 | | | (124,939) | |
| Changes in other regulatory liabilities | Changes in other regulatory liabilities | | 87,823 | | | (42,203) | | Changes in other regulatory liabilities | | (40,596) | | | 87,823 | |
| Effect of securitization on regulatory asset | | Effect of securitization on regulatory asset | | (1,190,338) | | | — | |
| | Changes in pension and other postretirement liabilities | Changes in pension and other postretirement liabilities | | (43,936) | | | (34,280) | | Changes in pension and other postretirement liabilities | | (17,123) | | | (43,936) | |
| Other | Other | | (84,588) | | | 39,034 | | Other | | 231,425 | | | (84,588) | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 519,407 | | | 726,789 | | Net cash flow provided by operating activities | | 206,713 | | | 519,407 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (1,655,993) | | | (690,049) | | Construction expenditures | | (1,565,051) | | | (1,655,993) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 12,936 | | | 20,942 | | Allowance for equity funds used during construction | | 9,585 | | | 12,936 | |
| Payment for purchase of assets | | 0 | | | (14,511) | | |
| | Nuclear fuel purchases | Nuclear fuel purchases | | (63,479) | | | (24,086) | | Nuclear fuel purchases | | (77,561) | | | (63,479) | |
| Proceeds from the sale of nuclear fuel | Proceeds from the sale of nuclear fuel | | 0 | | | 35,041 | | Proceeds from the sale of nuclear fuel | | 37,634 | | | — | |
| Receipts from storm reserve escrow account | Receipts from storm reserve escrow account | | 0 | | | 40,589 | | Receipts from storm reserve escrow account | | 1,000,217 | | | — | |
| | Payments to storm reserve escrow account | Payments to storm reserve escrow account | | 0 | | | (1,398) | | Payments to storm reserve escrow account | | (1,290,282) | | | — | |
| | Purchase of preferred membership interests of affiliate | | Purchase of preferred membership interests of affiliate | | (3,163,572) | | | — | |
| Redemption of preferred membership interests of affiliate | | Redemption of preferred membership interests of affiliate | | 1,390,587 | | | — | |
| Changes to securitization account | Changes to securitization account | | (956) | | | 755 | | Changes to securitization account | | — | | | (956) | |
| Proceeds from nuclear decommissioning trust fund sales | Proceeds from nuclear decommissioning trust fund sales | | 459,326 | | | 223,736 | | Proceeds from nuclear decommissioning trust fund sales | | 411,600 | | | 459,326 | |
| Investment in nuclear decommissioning trust funds | Investment in nuclear decommissioning trust funds | | (498,332) | | | (240,559) | | Investment in nuclear decommissioning trust funds | | (419,873) | | | (498,332) | |
| Changes in money pool receivable - net | Changes in money pool receivable - net | | (90,225) | | | (87,635) | | Changes in money pool receivable - net | | 7,162 | | | (90,225) | |
| | Litigation proceeds from settlement agreement | | Litigation proceeds from settlement agreement | | 5,695 | | | — | |
| | Litigation proceeds for reimbursement of spent nuclear fuel storage costs | | 0 | | | 5,090 | | |
| | Net cash flow used in investing activities | Net cash flow used in investing activities | | (1,836,723) | | | (732,085) | | Net cash flow used in investing activities | | (3,653,859) | | | (1,836,723) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | | 2,097,214 | | | 1,401,887 | | Proceeds from the issuance of long-term debt | | 1,777,192 | | | 2,097,214 | |
| Retirement of long-term debt | Retirement of long-term debt | | (1,296,875) | | | (826,456) | | Retirement of long-term debt | | (2,327,116) | | | (1,296,875) | |
| Proceeds from trust related to securitization | | Proceeds from trust related to securitization | | 3,163,572 | | | — | |
| Capital contribution from parent | | Capital contribution from parent | | 1,000,000 | | | — | |
| | Change in money pool payable - net | | 0 | | | (82,826) | | |
| Distributions paid: | | |
| | Common equity distributions paid | Common equity distributions paid | | 0 | | | (16,500) | | Common equity distributions paid | | (125,000) | | | — | |
| | Other | Other | | (4,169) | | | (9,080) | | Other | | 6,096 | | | (4,169) | |
| Net cash flow provided by financing activities | Net cash flow provided by financing activities | | 796,170 | | | 467,025 | | Net cash flow provided by financing activities | | 3,494,744 | | | 796,170 | |
| | Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | | (521,146) | | | 461,729 | | Net increase (decrease) in cash and cash equivalents | | 47,598 | | | (521,146) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 728,020 | | | 2,006 | | Cash and cash equivalents at beginning of period | | 18,573 | | | 728,020 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $206,874 | | | $463,735 | | Cash and cash equivalents at end of period | | $66,171 | | | $206,874 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | |
| Cash paid (received) during the period for: | | |
| Cash paid during the period for: | | Cash paid during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $165,480 | | | $157,926 | | Interest - net of amount capitalized | | $183,686 | | | $165,480 | |
| Income taxes | | $0 | | | ($20,684) | | |
| | | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | CURRENT ASSETS | |
| Cash and cash equivalents: | Cash and cash equivalents: | | Cash and cash equivalents: | |
| Cash | Cash | | $231 | | | $1,303 | | Cash | | $454 | | | $195 | |
| Temporary cash investments | Temporary cash investments | | 206,643 | | | 726,717 | | Temporary cash investments | | 65,717 | | | 18,378 | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 206,874 | | | 728,020 | | Total cash and cash equivalents | | 66,171 | | | 18,573 | |
| | Accounts receivable: | Accounts receivable: | | | | | Accounts receivable: | | | | |
| Customer | Customer | | 336,478 | | | 317,905 | | Customer | | 373,359 | | | 355,265 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | (39,793) | | | (45,693) | | Allowance for doubtful accounts | | (7,654) | | | (29,231) | |
| Associated companies | Associated companies | | 191,251 | | | 81,624 | | Associated companies | | 113,492 | | | 96,539 | |
| Other | Other | | 36,096 | | | 41,760 | | Other | | 48,814 | | | 36,674 | |
| Accrued unbilled revenues | Accrued unbilled revenues | | 206,910 | | | 178,840 | | Accrued unbilled revenues | | 213,199 | | | 174,768 | |
| Total accounts receivable | Total accounts receivable | | 730,942 | | | 574,436 | | Total accounts receivable | | 741,210 | | | 634,015 | |
| | Deferred fuel costs | Deferred fuel costs | | 98,679 | | | 2,250 | | Deferred fuel costs | | 412,695 | | | 45,374 | |
| Fuel inventory | Fuel inventory | | 51,920 | | | 50,680 | | Fuel inventory | | 43,141 | | | 42,958 | |
| Materials and supplies - at average cost | Materials and supplies - at average cost | | 443,275 | | | 437,933 | | Materials and supplies - at average cost | | 516,412 | | | 485,325 | |
| Deferred nuclear refueling outage costs | Deferred nuclear refueling outage costs | | 63,843 | | | 48,407 | | Deferred nuclear refueling outage costs | | 100,751 | | | 39,582 | |
| | Prepayments and other | Prepayments and other | | 51,441 | | | 36,813 | | Prepayments and other | | 84,504 | | | 44,187 | |
| TOTAL | TOTAL | | 1,646,974 | | | 1,878,539 | | TOTAL | | 1,964,884 | | | 1,310,014 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | OTHER PROPERTY AND INVESTMENTS | |
| Investment in affiliate preferred membership interests | Investment in affiliate preferred membership interests | | 1,390,587 | | | 1,390,587 | | Investment in affiliate preferred membership interests | | 3,163,572 | | | 1,390,587 | |
| Decommissioning trust funds | Decommissioning trust funds | | 1,985,477 | | | 1,794,042 | | Decommissioning trust funds | | 1,756,483 | | | 2,114,523 | |
| | Storm reserve escrow account | | Storm reserve escrow account | | 290,065 | | | — | |
| Non-utility property - at cost (less accumulated depreciation) | Non-utility property - at cost (less accumulated depreciation) | | 333,392 | | | 323,110 | | Non-utility property - at cost (less accumulated depreciation) | | 339,975 | | | 337,247 | |
| | Other | Other | | 13,500 | | | 13,399 | | Other | | 13,992 | | | 13,744 | |
| TOTAL | TOTAL | | 3,722,956 | | | 3,521,138 | | TOTAL | | 5,564,087 | | | 3,856,101 | |
| | UTILITY PLANT | UTILITY PLANT | | UTILITY PLANT | |
| Electric | Electric | | 26,204,300 | | | 25,619,789 | | Electric | | 26,976,504 | | | 28,055,038 | |
| | Natural gas | Natural gas | | 271,712 | | | 262,744 | | Natural gas | | 292,065 | | | 285,006 | |
| | Construction work in progress | Construction work in progress | | 577,975 | | | 667,281 | | Construction work in progress | | 785,737 | | | 847,924 | |
| Nuclear fuel | Nuclear fuel | | 224,870 | | | 210,128 | | Nuclear fuel | | 184,700 | | | 209,418 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 27,278,857 | | | 26,759,942 | | TOTAL UTILITY PLANT | | 28,239,006 | | | 29,397,386 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 9,610,279 | | | 9,372,224 | | Less - accumulated depreciation and amortization | | 10,065,760 | | | 9,860,252 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 17,668,578 | | | 17,387,718 | | UTILITY PLANT - NET | | 18,173,246 | | | 19,537,134 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | DEFERRED DEBITS AND OTHER ASSETS | |
| Regulatory assets: | Regulatory assets: | | Regulatory assets: | |
| | Other regulatory assets (includes securitization property of $0 as of June 30, 2021 and $5,088 as of December 31, 2020) | | 1,851,005 | | | 1,726,066 | | |
| Other regulatory assets | | Other regulatory assets | | 1,916,758 | | | 2,776,666 | |
| Deferred fuel costs | Deferred fuel costs | | 168,122 | | | 168,122 | | Deferred fuel costs | | 168,122 | | | 168,122 | |
| Other | Other | | 33,094 | | | 23,924 | | Other | | 40,203 | | | 27,801 | |
| TOTAL | TOTAL | | 2,052,221 | | | 1,918,112 | | TOTAL | | 2,125,083 | | | 2,972,589 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $25,090,729 | | | $24,705,507 | | TOTAL ASSETS | | $27,827,300 | | | $27,675,838 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | CURRENT LIABILITIES | |
| Currently maturing long-term debt | Currently maturing long-term debt | | $0 | | | $240,000 | | Currently maturing long-term debt | | $200,000 | | | $200,000 | |
| | Accounts payable: | Accounts payable: | | Accounts payable: | |
| Associated companies | Associated companies | | 116,333 | | | 103,148 | | Associated companies | | 123,940 | | | 183,172 | |
| Other | Other | | 476,177 | | | 1,450,008 | | Other | | 882,132 | | | 1,481,902 | |
| Customer deposits | Customer deposits | | 151,053 | | | 152,612 | | Customer deposits | | 156,467 | | | 150,697 | |
| Taxes accrued | Taxes accrued | | 97,467 | | | 42,617 | | Taxes accrued | | 62,562 | | | 64,248 | |
| | Interest accrued | Interest accrued | | 94,411 | | | 92,249 | | Interest accrued | | 89,789 | | | 93,052 | |
| | Current portion of unprotected excess accumulated deferred income taxes | Current portion of unprotected excess accumulated deferred income taxes | | 31,138 | | | 31,138 | | Current portion of unprotected excess accumulated deferred income taxes | | 6,073 | | | 24,291 | |
| Other | Other | | 62,057 | | | 62,968 | | Other | | 88,718 | | | 68,995 | |
| TOTAL | TOTAL | | 1,028,636 | | | 2,174,740 | | TOTAL | | 1,609,681 | | | 2,266,357 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | NON-CURRENT LIABILITIES | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 2,230,734 | | | 2,138,522 | | Accumulated deferred income taxes and taxes accrued | | 2,235,221 | | | 2,433,854 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 104,953 | | | 107,317 | | Accumulated deferred investment tax credits | | 100,228 | | | 102,588 | |
| Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 425,192 | | | 447,628 | | Regulatory liability for income taxes - net | | 303,290 | | | 313,693 | |
| | Other regulatory liabilities | Other regulatory liabilities | | 1,028,552 | | | 918,293 | | Other regulatory liabilities | | 1,030,622 | | | 1,042,597 | |
| Decommissioning | Decommissioning | | 1,612,748 | | | 1,573,307 | | Decommissioning | | 1,694,679 | | | 1,653,198 | |
| Accumulated provisions | Accumulated provisions | | 24,648 | | | 24,939 | | Accumulated provisions | | 318,557 | | | 24,490 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | 648,825 | | | 692,728 | | Pension and other postretirement liabilities | | 511,136 | | | 528,213 | |
| Long-term debt (includes securitization bonds of $0as of June 30, 2021 and $10,278 as of December 31, 2020) | | 9,836,133 | | | 8,787,451 | | |
| Long-term debt | | Long-term debt | | 10,169,840 | | | 10,714,346 | |
| | Other | Other | | 381,914 | | | 382,894 | | Other | | 300,449 | | | 415,930 | |
| TOTAL | TOTAL | | 16,293,699 | | | 15,073,079 | | TOTAL | | 16,664,022 | | | 17,228,909 | |
| | Commitments and Contingencies | Commitments and Contingencies | | Commitments and Contingencies | |
| | EQUITY | EQUITY | | EQUITY | |
| | Member's equity | Member's equity | | 7,763,886 | | | 7,453,361 | | Member's equity | | 9,514,529 | | | 8,172,294 | |
| Accumulated other comprehensive income | Accumulated other comprehensive income | | 4,508 | | | 4,327 | | Accumulated other comprehensive income | | 7,174 | | | 8,278 | |
| Noncontrolling interest | | Noncontrolling interest | | 31,894 | | | — | |
| TOTAL | TOTAL | | 7,768,394 | | | 7,457,688 | | TOTAL | | 9,553,597 | | | 8,180,572 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $25,090,729 | | | $24,705,507 | | TOTAL LIABILITIES AND EQUITY | | $27,827,300 | | | $27,675,838 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY | CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY | CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | Common Equity | | |
| Member’s
Equity | | Accumulated
Other
Comprehensive
Income | | Total | |
| (In Thousands) | |
| | Balance at December 31, 2019 | $6,392,556 | | | $4,562 | | | $6,397,118 | | |
| | Net income | 189,396 | | | 0 | | | 189,396 | | |
| Other comprehensive income | 0 | | | 9,467 | | | 9,467 | | |
| | Distributions declared on common equity | (11,500) | | | 0 | | | (11,500) | | |
| | Other | (10) | | | 0 | | | (10) | | |
| Balance at March 31, 2020 | 6,570,442 | | | 14,029 | | | 6,584,471 | | |
| | Net income | 170,459 | | | 0 | | | 170,459 | | |
| Other comprehensive loss | 0 | | | (945) | | | (945) | | |
| | Distributions declared on common equity | (5,000) | | | 0 | | | (5,000) | | |
| | Other | (13) | | | 0 | | | (13) | | |
| Balance at June 30, 2020 | $6,735,888 | | | $13,084 | | | $6,748,972 | | |
| | | | | Noncontrolling Interest | | Member’s
Equity | | Accumulated
Other
Comprehensive
Income | | Total |
| | | (In Thousands) |
| | Balance at December 31, 2020 | Balance at December 31, 2020 | $7,453,361 | | | $4,327 | | | $7,457,688 | | Balance at December 31, 2020 | $— | | | $7,453,361 | | | $4,327 | | | $7,457,688 | |
| | Net income | Net income | 166,626 | | | 0 | | | 166,626 | | Net income | — | | | 166,626 | | | — | | | 166,626 | |
| Other comprehensive loss | Other comprehensive loss | 0 | | | (407) | | | (407) | | Other comprehensive loss | — | | | — | | | (407) | | | (407) | |
| | | Other | Other | (16) | | | 0 | | | (16) | | Other | — | | | (16) | | | — | | | (16) | |
| Balance at March 31, 2021 | Balance at March 31, 2021 | 7,619,971 | | | 3,920 | | | 7,623,891 | | Balance at March 31, 2021 | — | | | 7,619,971 | | | 3,920 | | | 7,623,891 | |
| | Net income | Net income | 143,927 | | | 0 | | | 143,927 | | Net income | — | | | 143,927 | | | — | | | 143,927 | |
| Other comprehensive income | 0 | | | 588 | | | 588 | | |
| Other comprehensive loss | | Other comprehensive loss | — | | | — | | | 588 | | | 588 | |
| | Other | Other | (12) | | | 0 | | | (12) | | Other | — | | | (12) | | | — | | | (12) | |
| Balance at June 30, 2021 | Balance at June 30, 2021 | $7,763,886 | | | $4,508 | | | $7,768,394 | | Balance at June 30, 2021 | $— | | | $7,763,886 | | | $4,508 | | | $7,768,394 | |
| | | Balance at December 31, 2021 | | Balance at December 31, 2021 | $— | | | $8,172,294 | | | $8,278 | | | $8,180,572 | |
| | Net income | | Net income | — | | | 150,860 | | | — | | | 150,860 | |
| Other comprehensive loss | | Other comprehensive loss | — | | | — | | | (613) | | | (613) | |
| | Common equity distributions | | Common equity distributions | — | | | (125,000) | | | — | | | (125,000) | |
| | Other | | Other | — | | | (13) | | | — | | | (13) | |
| Balance at March 31, 2022 | | Balance at March 31, 2022 | — | | | 8,198,141 | | | 7,665 | | | 8,205,806 | |
| | Net income | | Net income | 258 | | | 316,401 | | | — | | | 316,659 | |
| Other comprehensive income | | Other comprehensive income | — | | | — | | | (491) | | | (491) | |
| | Capital contribution from parent | | Capital contribution from parent | — | | | 1,000,000 | | | — | | | 1,000,000 | |
| | Beneficial interest in storm trust | | Beneficial interest in storm trust | 31,636 | | | — | | | — | | | 31,636 | |
| Other | | Other | — | | | (13) | | | — | | | (13) | |
| Balance at June 30, 2022 | | Balance at June 30, 2022 | $31,894 | | | $9,514,529 | | | $7,174 | | | $9,553,597 | |
| | | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS -February 2021 Winter Storms��� in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in Entergy Mississippi’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Mississippi were approximately $65 million in February 2021 compared to approximately $35 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of storm cost recovery and fuel cost recovery at Entergy Mississippi.
In February 2021 the MPSC announced that it would launch a comprehensive review of the condition and resiliency of the state’s public utility infrastructure in response to the impacts of the February 2021 winter storms. Although the MPSC did not open a formal docket, the MPSC submitted data requests to Entergy Mississippi regarding the actions taken to ensure reliable operations of the electric network during the winter storm events and in anticipation of other future extreme weather events. In April 2021, Entergy Mississippi submitted responses to the MPSC data requests.
In April 2021 the MPSC opened a proceeding to investigate Entergy Mississippi’s membership in MISO. In the order, the MPSC noted the impact of the February 2021 winter storms, stating that it observed “excessive prices of natural gas and electricity” during the winter event. Entergy Mississippi submitted comments in the proceeding in June 2021.
Results of Operations
Net Income
Second Quarter 20212022 Compared to Second Quarter 20202021
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 $12.5$1.9 million primarily due to higher retail electric price, higher volume/weather, and higher volume/weather,other income, partially offset by higher other operation and maintenance expenses, higher taxes other than income taxes, and higher depreciation and amortization expenses.
Six Months Ended June 30,regulatory credits recorded in the second quarter 2021 Compared to Six Months Ended June 30, 2020
Net income increased $16 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher other operation and maintenance expenses,reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding, higher depreciation and amortization expenses, and a higher effective income tax rate.interest expense.
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
Operating Revenues
Second Quarter 20212022 Compared to Second Quarter 20202021
Following is an analysis of the change in operating revenues comparing the second quarter 20212022 to the second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $298349.0 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 37.933.9 | |
| Volume/weather | 12.1 | |
| Retail electric price | 8.610.5 | |
Volume/weather | 4.5 | |
20212022 operating revenues | $349405.5 | |
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 an interim increaseincreases in formula rate plan rates effective in part, with the first billing cycle ofJuly 2021 and April 2021.2022. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings.
The volume/weather variance is primarily due to an increase of 73 GWh, or 3%, in billed electricity usage primarily due to an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Total electric energy sales for Entergy Mississippi for the three months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 1,095 | | | 1,117 | | | (2) | | Residential | 1,419 | | | 1,281 | | | 11 | |
| Commercial | Commercial | 1,041 | | | 967 | | | 8 | | Commercial | 1,167 | | | 1,108 | | | 5 | |
| Industrial | Industrial | 576 | | | 562 | | | 2 | | Industrial | 593 | | | 585 | | | 1 | |
| Governmental | Governmental | 97 | | | 90 | | | 8 | | Governmental | 106 | | | 101 | | | 5 | |
| Total retail | Total retail | 2,809 | | | 2,736 | | | 3 | | Total retail | 3,285 | | | 3,075 | | | 7 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Non-associated companies | Non-associated companies | 1,643 | | | 1,039 | | | 58 | | Non-associated companies | 677 | | | 1,643 | | | (59) | |
| Total | Total | 4,452 | | | 3,775 | | | 18 | | Total | 3,962 | | | 4,718 | | | (16) | |
See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 20202021
Following is an analysis of the change in operating revenues comparing the six months ended June 30, 20212022 to the six months ended June 30, 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $591.9685.7 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 60.931.6 | |
| Retail electric price | 20.926.9 | |
| Volume/weather | 12.010.3 | |
20212022 operating revenues | $685.7754.5 | |
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 in part, with the first billing cycles of April 20202021, July 2021, and April 2021 and the implementation of a vegetation management rider effective with the April 2020 billing cycle.2022. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings and the vegetation management rider.filings.
The volume/weather variance is primarily due to an increase of 286 GWh, or 5%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in commercial usage.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.
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Total electric energy sales for Entergy Mississippi for the six months ended June 30,2021 2022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 2,590 | | | 2,367 | | | 9 | | Residential | 2,714 | | | 2,630 | | | 3 | |
| Commercial | Commercial | 2,050 | | | 1,973 | | | 4 | | Commercial | 2,188 | | | 2,112 | | | 4 | |
| Industrial | Industrial | 1,096 | | | 1,118 | | | (2) | | Industrial | 1,154 | | | 1,112 | | | 4 | |
| Governmental | Governmental | 192 | | | 184 | | | 4 | | Governmental | 201 | | | 197 | | | 2 | |
| Total retail | Total retail | 5,928 | | | 5,642 | | | 5 | | Total retail | 6,257 | | | 6,051 | | | 3 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Non-associated companies | Non-associated companies | 3,096 | | | 1,866 | | | 66 | | Non-associated companies | 1,212 | | | 3,096 | | | (61) | |
| Total | Total | 9,024 | | | 7,508 | | | 20 | | Total | 7,469 | | | 9,147 | | | (18) | |
See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
Other Income Statement Variances
Second Quarter 20212022 Compared to Second Quarter 2020
Other operation and maintenance expenses increased primarily due to:
•an increase of $4.1 million in distribution operations expenses primarily due to higher distribution reliability costs and higher vegetation maintenance costs;
•an increase of $2 million in information technology costs due to higher contract costs and higher costs associated with system maintenance;
•an increase of $1.3 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and
•an increase of $1.1 million as a result of the amount of transmission costs allocated by MISO.
The increase was partially offset by a decrease of $2 million due to the timing of recovery of energy efficiency costs.2021
Taxes other than income taxes increased primarily due to increases in ad valorem taxes. Ad valorem taxes increased primarily due toresulting from higher assessments.assessments and millage rate increases.
Depreciation and amortization expenses increased primarily as a resultdue 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 hereinin the Form 10-K for discussion of the 2021 formula rate plan filing.
Six Months Ended June 30, 2021 ComparedOther income increased primarily due to Six Months Ended June 30, 2020higher interest income from carrying costs related to the deferred fuel balance.
Other operation and maintenance expenses increased primarily due to:
•an increase of $5.3 million in vegetation maintenance costs;
•an increase of $2.5 million as a result of the amount of transmission costs allocated by MISO;
•an increase of $1.8 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and
•several individually insignificant items.
The increase was partially offset by a decrease of $3.1 million due to the timing of recovery of energy efficiency costs.
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Depreciation and amortization expenses increased primarily as a result of additions to plant in service.
Taxes other than income taxesInterest expense increased primarily due to increasesthe issuance of $200 million of 3.50% Series mortgage bonds in ad valorem taxes. Ad valorem taxes increased primarily due to higher assessments.
Other regulatory charges (credits) - net includes regulatory creditsMarch 2021 and the issuance of $19.9$200 million recordedof 2.55% Series mortgage bonds in the second quarter 2021, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.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.
The effective income tax rate was 22.6% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.
The effective income tax rate was 17.8% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $18 | | | $51,601 | | Cash and cash equivalents at beginning of period | $47,627 | | | $18 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 121,636 | | | 112,422 | | Operating activities | 20,404 | | | 121,636 | |
| Investing activities | Investing activities | (323,460) | | | (261,597) | | Investing activities | (295,818) | | | (323,460) | |
| Financing activities | Financing activities | 201,817 | | | 167,758 | | Financing activities | 253,895 | | | 201,817 | |
| Net increase (decrease) in cash and cash equivalents | (7) | | | 18,583 | | |
| Net decrease in cash and cash equivalents | | Net decrease in cash and cash equivalents | (21,519) | | | (7) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $11 | | | $70,184 | | Cash and cash equivalents at end of period | $26,108 | | | $11 | |
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
Operating Activities
Net cash flow provided by operating activities increased $9.2decreased by $101.2 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to the timing of payments to vendors.vendors, increased fuel costs, and income tax refunds of $8 million received in 2021 in accordance with an intercompany income tax allocation agreement. The increasedecrease was partially offset by increased fuel costs as a result of Winter Storm Uri, the timing ofhigher collections of receivables from customers in part due to the COVID-19 pandemic, and an increasea decrease of approximately $14.1$17.5 million in storm spending in 2021,2022, primarily due to Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. restoration efforts in 2021. See Note 2 to the financial statements in the Form 10-Kherein for a discussion of fuel and purchased power cost recovery.
Investing Activities
Net cash flow used in investing activities increased $61.9decreased $27.6 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•an increaseto a decrease of $86.2$91.8 million in distribution construction expenditures primarily due to increased spending on the reliabilitya higher scope of work performed in 2021 as compared to 2022, lower capital expenditures for storm restoration in 2022, and infrastructure of Entergy Mississippi’s distribution system and stormlower spending in 2021; and
•2022 on advanced metering infrastructure, as well as money pool activity.
The increasedecrease was partially offset by $24.6the initial payment of approximately $105.1 million in plant upgrades
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
May 2022 for Choctaw Generating Station in March 2020.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 $31.4$37.5 million for the six months ended June 30, 2020.2022. 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 $34.1$52.1 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 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, partially offset by the issuance of $170 million of 3.50% Series mortgage bonds in May 2020. 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 $200 million of mortgage bondslong-term debt in March 2021.2022.
| | | June 30,
2021 | | December 31,
2020 | | June 30,
2022 | | December 31,
2021 |
| Debt to capital | Debt to capital | 53.2 | % | | 51.7 | % | Debt to capital | 55.9 | % | | 54.3 | % |
| Effect of subtracting cash | Effect of subtracting cash | — | % | | — | % | Effect of subtracting cash | (0.3 | %) | | (0.5 | %) |
| Net debt to net capital | Net debt to net capital | 53.2 | % | | 51.7 | % | Net debt to net capital | 55.6 | % | | 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
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
evaluating Entergy Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.
Uses and Sources of Capital
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Mississippi’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Following are the current annual amounts of Entergy Mississippi’s planned construction and other capital investments.
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2023 | | 2024 |
| | (In Millions) |
| Planned construction and capital investment: | | | | | |
| Generation | $225 | | | $85 | | | $50 | |
| Transmission | 85 | | | 115 | | | 120 | |
| Distribution | 230 | | | 250 | | | 225 | |
| Utility Support | 100 | | | 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,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31,
2019 |
| (In Thousands) |
| ($16,998) | | ($16,516) | | $13,311 | | $44,693 |
| | | | | | | | | | | | | | | | | | | | |
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 $82.5$95 million scheduled to expire in April 2022. No2023. As of June 30, 2022, there were no cash borrowings wereoutstanding 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 facilities as of June 30, 2021.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, 2021, $22022, $4.3 million ofin MISO letters of credit and $7.9$7 million ofin non-MISO letters of credit were outstanding under this facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.
Entergy Mississippi has $33had $33.2 million in its storm reserve escrow account at June 30, 2021.2022.
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.
Entergy Mississippi, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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.
2021Fuel 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 2021,2022, Entergy Mississippi submitted its formula rate plan 20212022 test year filing and 20202021 look-back filing showing Entergy Mississippi’s earned return for the historical 20202021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 20212022 calendar year to be below the formula rate plan bandwidth. The 20212022 test year filing shows a $95.4$69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69%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 $44.3$48.6 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 20202021 results to the approved benchmark return on rate base and reflects the need for a $16.8$34.5 million interim increase in formula rate plan revenues. In addition,fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increasesthen-current estimate in connection with the look-back interimfeature of the formula rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million.plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1$24.3 million interim rate increase, reflecting a cap equal to 2% of 20202021 retail revenues, effective with thein April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap
Entergy Mississippi, LLC
Management's Financial Discussion and Analysis
of 2020 retail revenues, were included in the April 2021 rate adjustments.2022.
In June 2021,2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 20212022 test year filing that resulted in a total rate increase of $48.2$48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 20202021 look-back filing reflected an earned return on rate base of 6.12%5.99% in calendar year 2020,2021, which is below the look-back bandwidth, resulting in a $17.5$34.3 million increase in the formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses.June 2023. In June 2021July 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 first billing cycle2 cents per kWh low-income benefits adder to households up to 250% of July 2021. In June 2021, the federal poverty level and grandfathers that adder for 25 years. The amended rule expands meter aggregation to include
Entergy Mississippi, recorded regulatory assets of $19.9 millionLLC and Subsidiaries
Management's Financial Discussion and Analysis
systems up to reflect3 MW alternating current and to any additional meters within the effectssame 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 joint stipulation.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 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021,2022, Entergy Mississippi recordedhad a regulatory asset of $19.3$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 “
Entergy Mississippi, LLC
Management'sCorporation 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.
| | ENTERGY MISSISSIPPI, LLC | |
| INCOME STATEMENTS | |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES | | ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS | | CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $349,040 | | | $297,954 | | | $685,659 | | | $591,876 | | Electric | | $405,459 | | | $349,040 | | | $754,488 | | | $685,659 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 65,613 | | | 38,730 | | | 125,810 | | | 102,027 | | Fuel, fuel-related expenses, and gas purchased for resale | | 43,671 | | | 65,613 | | | 110,948 | | | 125,810 | |
| Purchased power | Purchased power | | 63,892 | | | 56,679 | | | 132,483 | | | 109,322 | | Purchased power | | 89,346 | | | 63,892 | | | 150,558 | | | 132,483 | |
| Other operation and maintenance | Other operation and maintenance | | 73,899 | | | 66,343 | | | 141,730 | | | 128,680 | | Other operation and maintenance | | 74,898 | | | 73,899 | | | 140,709 | | | 141,730 | |
| | Taxes other than income taxes | Taxes other than income taxes | | 27,076 | | | 22,697 | | | 52,975 | | | 49,887 | | Taxes other than income taxes | | 32,484 | | | 27,076 | | | 65,214 | | | 52,975 | |
| Depreciation and amortization | Depreciation and amortization | | 56,158 | | | 52,296 | | | 111,194 | | | 103,451 | | Depreciation and amortization | | 60,618 | | | 56,158 | | | 120,702 | | | 111,194 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | (21,630) | | | (6,496) | | | (13,501) | | | (10,377) | | Other regulatory charges (credits) - net | | 23,853 | | | (21,630) | | | 27,760 | | | (13,501) | |
| TOTAL | TOTAL | | 265,008 | | | 230,249 | | | 550,691 | | | 482,990 | | TOTAL | | 324,870 | | | 265,008 | | | 615,891 | | | 550,691 | |
| | OPERATING INCOME | OPERATING INCOME | | 84,032 | | | 67,705 | | | 134,968 | | | 108,886 | | OPERATING INCOME | | 80,589 | | | 84,032 | | | 138,597 | | | 134,968 | |
| | OTHER DEDUCTIONS | | |
| OTHER INCOME (DEDUCTIONS) | | OTHER INCOME (DEDUCTIONS) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 2,029 | | | 1,588 | | | 3,697 | | | 3,027 | | Allowance for equity funds used during construction | | 1,495 | | | 2,029 | | | 2,573 | | | 3,697 | |
| Interest and investment income | Interest and investment income | | 7 | | | 135 | | | 49 | | | 255 | | Interest and investment income | | 34 | | | 7 | | | 98 | | | 49 | |
| Miscellaneous - net | Miscellaneous - net | | (2,205) | | | (2,589) | | | (4,518) | | | (4,885) | | Miscellaneous - net | | 990 | | | (2,205) | | | (164) | | | (4,518) | |
| TOTAL | TOTAL | | (169) | | | (866) | | | (772) | | | (1,603) | | TOTAL | | 2,519 | | | (169) | | | 2,507 | | | (772) | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 18,922 | | | 17,192 | | | 36,535 | | | 33,775 | | Interest expense | | 21,003 | | | 18,922 | | | 41,437 | | | 36,535 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (852) | | | (634) | | | (1,529) | | | (1,185) | | Allowance for borrowed funds used during construction | | (658) | | | (852) | | | (1,123) | | | (1,529) | |
| TOTAL | TOTAL | | 18,070 | | | 16,558 | | | 35,006 | | | 32,590 | | TOTAL | | 20,345 | | | 18,070 | | | 40,314 | | | 35,006 | |
| | INCOME BEFORE INCOME TAXES | INCOME BEFORE INCOME TAXES | | 65,793 | | | 50,281 | | | 99,190 | | | 74,693 | | INCOME BEFORE INCOME TAXES | | 62,763 | | | 65,793 | | | 100,790 | | | 99,190 | |
| | Income taxes | Income taxes | | 14,377 | | | 11,388 | | | 21,802 | | | 13,274 | | Income taxes | | 13,808 | | | 14,377 | | | 21,481 | | | 21,802 | |
| | NET INCOME | NET INCOME | | $51,416 | | | $38,893 | | | $77,388 | | | $61,419 | | NET INCOME | | 48,955 | | | 51,416 | | | 79,309 | | | 77,388 | |
| | Net income attributable to noncontrolling interest | | Net income attributable to noncontrolling interest | | — | | | — | | | — | | | — | |
| | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | EARNINGS APPLICABLE TO MEMBER'S EQUITY | | $48,955 | | | $51,416 | | | $79,309 | | | $77,388 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
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| | ENTERGY MISSISSIPPI, LLC | |
| STATEMENTS OF CASH FLOWS | |
| For the Six Months Ended June 30, 2021 and 2020 | |
| ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES | | ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | | CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | Net income | | $77,388 | | | $61,419 | | Net income | | $79,309 | | | $77,388 | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | Adjustments to reconcile net income to net cash flow provided by operating activities: | | Adjustments to reconcile net income to net cash flow provided by operating activities: | |
| Depreciation and amortization | Depreciation and amortization | | 111,194 | | | 103,451 | | Depreciation and amortization | | 120,702 | | | 111,194 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 33,499 | | | 13,126 | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 17,628 | | | 33,499 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Receivables | Receivables | | (9,164) | | | 7,076 | | Receivables | | (38,137) | | | (9,164) | |
| Fuel inventory | Fuel inventory | | 954 | | | (5,747) | | Fuel inventory | | (5,352) | | | 954 | |
| Accounts payable | Accounts payable | | 38,287 | | | 9,943 | | Accounts payable | | 23,252 | | | 38,287 | |
| Taxes accrued | Taxes accrued | | (49,438) | | | (34,195) | | Taxes accrued | | (36,021) | | | (49,438) | |
| Interest accrued | Interest accrued | | (4,623) | | | 1,399 | | Interest accrued | | 498 | | | (4,623) | |
| Deferred fuel costs | Deferred fuel costs | | (46,714) | | | (2,840) | | Deferred fuel costs | | (124,752) | | | (46,714) | |
| Other working capital accounts | Other working capital accounts | | (27,684) | | | 135 | | Other working capital accounts | | (36,211) | | | (27,684) | |
| Provisions for estimated losses | Provisions for estimated losses | | (7,860) | | | (1,782) | | Provisions for estimated losses | | (194) | | | (7,860) | |
| Other regulatory assets | Other regulatory assets | | (13,050) | | | (28,290) | | Other regulatory assets | | 3,332 | | | (13,050) | |
| Other regulatory liabilities | Other regulatory liabilities | | 13,520 | | | (11,548) | | Other regulatory liabilities | | 15,441 | | | 13,520 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | (10,086) | | | (5,353) | | Pension and other postretirement liabilities | | (8,004) | | | (10,086) | |
| Other assets and liabilities | Other assets and liabilities | | 15,413 | | | 5,628 | | Other assets and liabilities | | 8,913 | | | 15,413 | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 121,636 | | | 112,422 | | Net cash flow provided by operating activities | | 20,404 | | | 121,636 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (327,163) | | | (267,231) | | Construction expenditures | | (230,683) | | | (327,163) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 3,697 | | | 3,027 | | Allowance for equity funds used during construction | | 2,573 | | | 3,697 | |
| | Changes in money pool receivable - net | Changes in money pool receivable - net | | 0 | | | 31,382 | | Changes in money pool receivable - net | | 37,472 | | | — | |
| Payment for the purchase of plant or assets | Payment for the purchase of plant or assets | | 0 | | | (28,612) | | Payment for the purchase of plant or assets | | (105,149) | | | — | |
| | Other | Other | | 6 | | | (163) | | Other | | (31) | | | 6 | |
| Net cash flow used in investing activities | Net cash flow used in investing activities | | (323,460) | | | (261,597) | | Net cash flow used in investing activities | | (295,818) | | | (323,460) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | | 200,543 | | | 165,408 | | Proceeds from the issuance of long-term debt | | 249,746 | | | 200,543 | |
| | Capital contribution from noncontrolling interest | | Capital contribution from noncontrolling interest | | 9,595 | | | — | |
| Changes in money pool payable - net | Changes in money pool payable - net | | 482 | | | 0 | | Changes in money pool payable - net | | — | | | 482 | |
| | Common equity distributions paid | | 0 | | | (2,500) | | |
| | | Other | Other | | 792 | | | 4,850 | | Other | | (5,446) | | | 792 | |
| Net cash flow provided by financing activities | Net cash flow provided by financing activities | | 201,817 | | | 167,758 | | Net cash flow provided by financing activities | | 253,895 | | | 201,817 | |
| | Net increase (decrease) in cash and cash equivalents | | (7) | | | 18,583 | | |
| Net decrease in cash and cash equivalents | | Net decrease in cash and cash equivalents | | (21,519) | | | (7) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 18 | | | 51,601 | | Cash and cash equivalents at beginning of period | | 47,627 | | | 18 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $11 | | | $70,184 | | Cash and cash equivalents at end of period | | $26,108 | | | $11 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | |
| Cash paid (received) during the period for: | Cash paid (received) during the period for: | | Cash paid (received) during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $39,925 | | | $31,196 | | Interest - net of amount capitalized | | $39,620 | | | $39,925 | |
| Income taxes | Income taxes | | ($8,045) | | | $0 | | Income taxes | | $— | | | ($8,045) | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY MISSISSIPPI, LLC | |
| BALANCE SHEETS | |
| ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES | | ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | | CONSOLIDATED BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | | 2021 | | 2020 | | | 2022 | | 2021 |
| | | | (In Thousands) | | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | | | | CURRENT ASSETS | | | | |
| Cash and cash equivalents: | Cash and cash equivalents: | | | | | Cash and cash equivalents: | | | | |
| Cash | Cash | | $11 | | | $11 | | Cash | | $36 | | | $29 | |
| Temporary cash investments | Temporary cash investments | | 0 | | | 7 | | Temporary cash investments | | 26,072 | | | 47,598 | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 11 | | | 18 | | Total cash and cash equivalents | | 26,108 | | | 47,627 | |
| Accounts receivable: | Accounts receivable: | | | | | Accounts receivable: | | | | |
| Customer | Customer | | 91,479 | | | 105,732 | | Customer | | 93,171 | | | 84,048 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | (13,646) | | | (19,527) | | Allowance for doubtful accounts | | (2,222) | | | (7,209) | |
| Associated companies | Associated companies | | 4,226 | | | 2,740 | | Associated companies | | 13,526 | | | 42,994 | |
| Other | Other | | 15,985 | | | 11,821 | | Other | | 12,250 | | | 14,609 | |
| Accrued unbilled revenues | Accrued unbilled revenues | | 71,400 | | | 59,514 | | Accrued unbilled revenues | | 74,416 | | | 56,034 | |
| Total accounts receivable | Total accounts receivable | | 169,444 | | | 160,280 | | Total accounts receivable | | 191,141 | | | 190,476 | |
| Deferred fuel costs | Deferred fuel costs | | 32,023 | | | 0 | | Deferred fuel costs | | 246,630 | | | 121,878 | |
| | Fuel inventory - at average cost | Fuel inventory - at average cost | | 16,163 | | | 17,117 | | Fuel inventory - at average cost | | 15,663 | | | 10,311 | |
| Materials and supplies - at average cost | Materials and supplies - at average cost | | 65,915 | | | 59,542 | | Materials and supplies - at average cost | | 79,390 | | | 69,639 | |
| | Prepayments and other | Prepayments and other | | 22,447 | | | 4,876 | | Prepayments and other | | 28,494 | | | 6,394 | |
| TOTAL | TOTAL | | 306,003 | | | 241,833 | | TOTAL | | 587,426 | | | 446,325 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | | | | OTHER PROPERTY AND INVESTMENTS | | | | |
| Non-utility property - at cost (less accumulated depreciation) | Non-utility property - at cost (less accumulated depreciation) | | 4,535 | | | 4,543 | | Non-utility property - at cost (less accumulated depreciation) | | 4,519 | | | 4,527 | |
| Escrow accounts | Escrow accounts | | 48,932 | | | 64,635 | | Escrow accounts | | 41,067 | | | 48,886 | |
| TOTAL | TOTAL | | 53,467 | | | 69,178 | | TOTAL | | 45,586 | | | 53,413 | |
| | UTILITY PLANT | UTILITY PLANT | | | | | UTILITY PLANT | | | | |
| Electric | Electric | | 6,275,518 | | | 6,084,730 | | Electric | | 6,724,036 | | | 6,613,109 | |
| | Construction work in progress | Construction work in progress | | 172,783 | | | 134,854 | | Construction work in progress | | 266,686 | | | 95,452 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 6,448,301 | | | 6,219,584 | | TOTAL UTILITY PLANT | | 6,990,722 | | | 6,708,561 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 2,068,644 | | | 2,005,087 | | Less - accumulated depreciation and amortization | | 2,204,547 | | | 2,127,590 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 4,379,657 | | | 4,214,497 | | UTILITY PLANT - NET | | 4,786,175 | | | 4,580,971 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | | | | DEFERRED DEBITS AND OTHER ASSETS | | | | |
| Regulatory assets: | Regulatory assets: | | | | | Regulatory assets: | | | | |
| | Other regulatory assets | Other regulatory assets | | 480,391 | | | 467,341 | | Other regulatory assets | | 459,100 | | | 462,432 | |
| Other | Other | | 16,239 | | | 14,413 | | Other | | 18,613 | | | 14,248 | |
| TOTAL | TOTAL | | 496,630 | | | 481,754 | | TOTAL | | 477,713 | | | 476,680 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $5,235,757 | | | $5,007,262 | | TOTAL ASSETS | | $5,896,900 | | | $5,557,389 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | | | | See Notes to Financial Statements. | | | | |
| | ENTERGY MISSISSIPPI, LLC | |
| BALANCE SHEETS | |
| ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES | | ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | | CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | | 2021 | | 2020 | | | 2022 | | 2021 |
| | | | (In Thousands) | | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | | | | CURRENT LIABILITIES | | | | |
| | Accounts payable: | Accounts payable: | | | | | Accounts payable: | | | | |
| Associated companies | Associated companies | | $64,309 | | | $61,727 | | Associated companies | | $45,337 | | | $42,929 | |
| Other | Other | | 118,387 | | | 117,629 | | Other | | 133,452 | | | 113,000 | |
| Customer deposits | Customer deposits | | 86,028 | | | 86,200 | | Customer deposits | | 88,087 | | | 86,167 | |
| Taxes accrued | Taxes accrued | | 58,646 | | | 108,084 | | Taxes accrued | | 70,252 | | | 106,273 | |
| | Interest accrued | Interest accrued | | 16,266 | | | 20,889 | | Interest accrued | | 17,781 | | | 17,283 | |
| Deferred fuel costs | | 0 | | | 14,691 | | |
| | | Other | Other | | 23,075 | | | 34,270 | | Other | | 22,629 | | | 36,731 | |
| TOTAL | TOTAL | | 366,711 | | | 443,490 | | TOTAL | | 377,538 | | | 402,383 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | | | | NON-CURRENT LIABILITIES | | | | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 680,901 | | | 646,674 | | Accumulated deferred income taxes and taxes accrued | | 741,539 | | | 720,097 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 11,025 | | | 9,062 | | Accumulated deferred investment tax credits | | 10,801 | | | 10,913 | |
| | Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 219,343 | | | 224,000 | | Regulatory liability for income taxes - net | | 206,932 | | | 212,445 | |
| | Other regulatory liabilities | Other regulatory liabilities | | 34,005 | | | 15,828 | | Other regulatory liabilities | | 70,267 | | | 49,313 | |
| Asset retirement cost liabilities | Asset retirement cost liabilities | | 10,035 | | | 9,762 | | Asset retirement cost liabilities | | 10,603 | | | 10,315 | |
| Accumulated provisions | Accumulated provisions | | 38,644 | | | 46,504 | | Accumulated provisions | | 37,834 | | | 38,028 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | 100,700 | | | 110,901 | | Pension and other postretirement liabilities | | 50,945 | | | 59,065 | |
| Long-term debt | Long-term debt | | 1,981,674 | | | 1,780,577 | | Long-term debt | | 2,430,499 | | | 2,179,989 | |
| Other | Other | | 42,597 | | | 47,730 | | Other | | 31,469 | | | 35,273 | |
| TOTAL | TOTAL | | 3,118,924 | | | 2,891,038 | | TOTAL | | 3,590,889 | | | 3,315,438 | |
| | Commitments and Contingencies | Commitments and Contingencies | | | | | Commitments and Contingencies | | | | |
| | | EQUITY | EQUITY | | | | | EQUITY | | | | |
| Member's equity | Member's equity | | 1,750,122 | | | 1,672,734 | | Member's equity | | 1,918,878 | | | 1,839,568 | |
| Noncontrolling interest | | Noncontrolling interest | | 9,595 | | | — | |
| TOTAL | TOTAL | | 1,750,122 | | | 1,672,734 | | TOTAL | | 1,928,473 | | | 1,839,568 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $5,235,757 | | | $5,007,262 | | TOTAL LIABILITIES AND EQUITY | | $5,896,900 | | | $5,557,389 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | | | | See Notes to Financial Statements. | | | | |
| | | | | | | | |
ENTERGY MISSISSIPPI, LLC |
STATEMENTS OF CHANGES IN MEMBER'S EQUITY |
For the Six Months Ended June 30, 2021 and 2020 |
(Unaudited) |
| | |
| | |
| | Member's Equity |
| | (In Thousands) |
| | |
Balance at December 31, 2019 | | $1,542,151 | |
| | |
Net income | | 22,526 | |
Common equity distributions | | (2,500) | |
Balance at March 31, 2020 | | 1,562,177 | |
| | |
Net income | | 38,893 | |
| | |
Balance at June 30, 2020 | | $1,601,070 | |
| | |
| | |
| | |
| | |
| | |
| | |
Balance at December 31, 2020 | | $1,672,734 | |
| | |
Net income | | 25,972 | |
| | |
Balance at March 31, 2021 | | 1,698,706 | |
| | |
Net income | | 51,416 | |
| | |
Balance at June 30, 2021 | | $1,750,122 | |
| | |
| | |
| | |
| | |
| | |
See Notes to Financial Statements. | | |
| | | | | | | | | | | | | | | | | |
| ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) |
| | | | | |
| | | | | | |
| | Noncontrolling Interest | | Member's Equity | | Total |
| | | | (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 interest | 9,595 | | | — | | | 9,595 | |
| Balance at June 30, 2022 | $9,595 | | | $1,918,878 | | | $1,928,473 | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| See Notes to Financial Statements. | | | | | |
ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Hurricane Zeta
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Zeta, which caused significant damage to Entergy New Orleans’s service area. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. See Note 2 to the financial statements herein for discussion of the storm cost certification filing made in 2021 by Entergy New Orleans.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy New Orleans’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy New Orleans were approximately $35 million in February 2021 compared to approximately $25 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of fuel cost recovery at Entergy New Orleans. See “Load Shed Investigation” below for discussion of the investigation initiated by the City Council in February 2021.
Results of Operations
Net Income
Second Quarter 20212022 Compared to Second Quarter 20202021
Net income remained relatively unchanged, decreasing by $0.3increased $14.9 million primarily due to higher volume/weather and higher retail electric price, partially offset by higher other operation and maintenance expenses, partially offset by higher volume/weathertaxes other than income taxes, and higher retail electric price.interest expense.
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 20202021
Net income decreased $9.7increased $28.3 million primarily due to higher other operation and maintenance expenses and higher depreciation and amortization expenses, partially offset by higher retail electric price and higher volume/weather.weather, partially offset by higher interest expense and higher taxes other than income taxes.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Operating Revenues
Second Quarter 20212022 Compared to Second Quarter 20202021
Following is an analysis of the change in operating revenues comparing second quarter 20212022 to second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $147.3178.7 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 20.352.7 | |
| Volume/weather | 6.812.9 | |
| Retail electric price | 4.39.9 | |
20212022 operating revenues | $178.7254.2 | |
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 of 30 GWh, or 2%, in billed electricityweather-adjusted residential usage including increased commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year, partially offset byand the effect of lessmore favorable weather on commercial and residential sales. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
The retail electric price variance is primarily due to an interima rate increase effective November 2021 in accordance with the terms of the 2021 formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020.filing. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate case resolution.plan filing.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Total electric energy sales for Entergy New Orleans for the three months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | (GWh) | |
| Residential | Residential | 492 | | | 520 | | | (5) | | Residential | 669 | | | 563 | | | 19 | |
| Commercial | Commercial | 484 | | | 440 | | | 10 | | Commercial | 543 | | | 507 | | | 7 | |
| Industrial | Industrial | 108 | | | 106 | | | 2 | | Industrial | 116 | | | 111 | | | 5 | |
| Governmental | Governmental | 189 | | | 177 | | | 7 | | Governmental | 206 | | | 198 | | | 4 | |
| Total retail | Total retail | 1,273 | | | 1,243 | | | 2 | | Total retail | 1,534 | | | 1,379 | | | 11 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Non-associated companies | Non-associated companies | 530 | | | 473 | | | 12 | | Non-associated companies | 605 | | | 530 | | | 14 | |
| Total | Total | 1,803 | | | 1,716 | | | 5 | | Total | 2,139 | | | 1,909 | | | 12 | |
See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Six Months Ended June 30, 20212022 Compared to Six Months Ended June 30, 20202021
Following is an analysis of the change in operating revenues comparing the six months ended June 30, 20212022 to the six months ended June 30, 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $296.6348.1 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 25.668.5 | |
| Retail electric price | 19.620.2 | |
| Volume/weather | 6.315.7 | |
20212022 operating revenues | $348.1452.5 | |
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 an interima rate increase effective November 2021 in accordance with the terms of the 2021 formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020.filing. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate case resolution.plan filing.
The volume/weather variance is primarily due to an increase of 55 GWh, or 2%, in billed electricityweather-adjusted residential usage, includingan increase in commercial usage, and the effect of more favorable weather on residential sales, partially offset by lower volumesales. The increase in commercial usage was primarily due to the residential and industrial sectors.effect of the COVID-19 pandemic on businesses in 2021.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Total electric energy sales for Entergy New Orleans for the six months ended June 30,2021 2022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | (GWh) | |
| Residential | Residential | 1,087 | | | 1,021 | | | 6 | | Residential | 1,207 | | | 1,101 | | | 10 | |
| Commercial | Commercial | 933 | | | 936 | | | — | | Commercial | 1,008 | | | 953 | | | 6 | |
| Industrial | Industrial | 200 | | | 208 | | | (4) | | Industrial | 210 | | | 205 | | | 2 | |
| Governmental | Governmental | 361 | | | 361 | | | — | | Governmental | 383 | | | 370 | | | 4 | |
| Total retail | Total retail | 2,581 | | | 2,526 | | | 2 | | Total retail | 2,808 | | | 2,629 | | | 7 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Non-associated companies | Non-associated companies | 619 | | | 1,074 | | | (42) | | Non-associated companies | 1,321 | | | 619 | | | 113 | |
| Total | Total | 3,200 | | | 3,600 | | | (11) | | Total | 4,129 | | | 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.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Other Income Statement Variances
Second Quarter 2021 Compared to Second Quarter 2020
Other operation and maintenance expenses increasedThe 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:
•an increaseto state income taxes, partially offset by the amortization of $3.2 million dueexcess accumulated deferred income taxes and certain book and tax differences related to an increase in bad debt expense resulting from the COVID-19 pandemic.utility plant items. See Note 210 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity associated with the COVID-19 pandemic;
•an increase of $2.1 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages as compared to the same period in 2020Notes 2 and the New Orleans Power Station, which was placed in service in May 2020;
•an increase of $1.8 million in distribution expenses primarily due to higher distribution reliability and higher vegetation maintenance costs; and
•an increase of $1.7 million in energy efficiency costs.
Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the New Orleans Power Station and New Orleans Solar Station projects.
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Other operation and maintenance expenses increased primarily due to:
•an increase of $5.6 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages as compared to the same period in 2020 and the New Orleans Power Station, which was placed in service in May 2020;
•an increase of $5.3 million in energy efficiency costs;
•an increase of $3.8 million due to an increase in 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 $3.1 million in distribution expenses primarily due to higher distribution reliability and higher vegetation maintenance costs.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the New Orleans Power Station, which was placed in service in May 2020.
Other regulatory charges (credits) - net includes regulatory credits recorded in first quarter 2020 to reflect compliance with terms of the 2018 combined rate case resolution approved by the City Council in February 2020. See Note 23 to the financial statements in the Form 10-K for a discussion of the rate case resolution.
Other income decreased primarily due to a decrease ineffects of and regulatory activity regarding the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the New Orleans Power StationTax Cuts and New Orleans Solar Station projects.
Income TaxesJobs Act.
The effective income tax rate was 28% for second quarter 2021 and 29.8% for the six months ended June 30, 2021. The differencedifferences 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.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
The effective income tax rate was (53.5%) for second quarter 2020. The difference in the effective income tax rate for second quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes and the provision for uncertain tax positions. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.
The effective income tax rate was (38.2%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due tothe amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by the provision for uncertain tax positions and state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $26 | | | $6,017 | | Cash and cash equivalents at beginning of period | $42,862 | | | $26 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 27,188 | | | 24,660 | | Operating activities | 55,623 | | | 27,188 | |
| Investing activities | Investing activities | (48,660) | | | (112,552) | | Investing activities | (81,900) | | | (48,660) | |
| Financing activities | Financing activities | 21,472 | | | 112,620 | | Financing activities | 9,766 | | | 21,472 | |
| Net increase in cash and cash equivalents | — | | | 24,728 | | |
| Net decrease in cash and cash equivalents | | Net decrease in cash and cash equivalents | (16,511) | | | — | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $26 | | | $30,745 | | Cash and cash equivalents at end of period | $26,351 | | | $26 | |
Operating Activities
Net cash flow provided by operating activities increased $2.5$28.4 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to the timing of collection of receivableshigher collections from customers and payments to vendors and income tax payments of $0.3 million in 2021 compared to income tax payments of $3.3 million in 2020. Entergy New Orleans made income tax payments in 2020 in accordance with an intercompany tax allocation agreement.customers.
The increase was partially offset by:
•an increasethe timing of $5.1 millionpayments to vendors;
•increased fuel costs. See Note 2 to the financial statements in storm spending in 2021, primarily due to Hurricane Zeta restoration efforts. See “Hurricane Zeta” abovethe Form 10-K for a discussion of hurricane restoration efforts;fuel and purchased power cost recovery; and
•an increase of $2.1$12.7 million in pension contributionsstorm spending in 2021.2022, primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting EstimatesHurricane Ida” in the Form 10-K and Note 62 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.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
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Investing Activitiesan 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.
Net cash flows used in investing activities decreased $63.9 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:
•$44.2 million in receipts from storm reserve escrow accounts in 2021;
•The increase was partially offset by money pool activity and a decrease of $32.2$9.4 million in non-nuclear generation construction expenditures primarily due to a lower spendingscope of work performed during plant outages in 2021 on the New Orleans Power Station and the New Orleans Solar Station projects; and
•a decrease of $7.9 million in distribution construction expenditures primarily due to lower spending in 2021 on advanced metering infrastructure.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 decrease in distribution construction expenditures was partially offset bymoney pool is an increase of $14.4 million in storm spending in 2021. See “Hurricane Zeta” aboveinter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for discussion of hurricane restoration efforts.external short-term borrowings.
Financing Activities
Net cash flow provided by financing activities decreased $91.1$11.7 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to the issuance of $78 million of 3.00% Series mortgage bonds and the issuance of $62 million of 3.75% Series mortgage bonds, each in March 2020. The decrease wasmoney pool activity, partially offset by money pool activitya $15 million advance received in 2022 in anticipation of Entergy New Orleans’s construction of a New Orleans Sewerage and $20 million in repayments on long-term credit borrowings in 2020.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. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.
See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.
Capital Structure
Entergy New Orleans’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due an increase in equity resulting from retained earnings in 2022.
| | | June 30,
2021 | | December 31,
2020 | | June 30,
2022 | | December 31,
2021 |
| Debt to capital | Debt to capital | 51.5 | % | | 51.5 | % | Debt to capital | 53.9 | % | | 55.4 | % |
| Effect of excluding securitization bonds | Effect of excluding securitization bonds | (1.8 | %) | | (1.6 | %) | Effect of excluding securitization bonds | (0.8 | %) | | (1.0 | %) |
| Debt to capital, excluding securitization bonds (a) | Debt to capital, excluding securitization bonds (a) | 49.7 | % | | 49.9 | % | Debt to capital, excluding securitization bonds (a) | 53.1 | % | | 54.4 | % |
| Effect of subtracting cash | Effect of subtracting cash | — | % | | — | % | Effect of subtracting cash | (0.8 | %) | | (1.4 | %) |
| Net debt to net capital, excluding securitization bonds (a) | Net debt to net capital, excluding securitization bonds (a) | 49.7 | % | | 49.9 | % | 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
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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:
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2023 | | 2024 |
| | (In Millions) |
| Planned construction and capital investment: | | | | | |
| Generation | $5 | | | $5 | | | $5 | |
| Transmission | 20 | | | 20 | | | 20 | |
| Distribution | 110 | | | 115 | | | 190 | |
| Utility Support | 25 | | | 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,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31,
2019 |
| (In Thousands) |
| ($37,874) | | ($10,190) | | $5,777 | | $5,191 |
| | | | | | | | | | | | | | | | | | | | |
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, 2021,2022, 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, 2021,2022, 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 has $38.8filed 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
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
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 account at June 30, 2021.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
20212022 Formula Rate Plan Filing
In July 2021,April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 20202021 test year filing. The 20202021 test year evaluation report, subsequently updated in a July 2022 filing, produced an earned return on equity of 6.26%6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64$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 $40$34.1 million and an increase in authorized gas revenues of $18.8$3.3 million. Entergy New Orleans also seeks to commence collecting $5.2$4.7 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review byIn July 2022 the City CouncilCouncil’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 othergas revenues. The parties over a 75-day review period, followed byhave a 25-day period to resolve any disputes amongattempt to reach an agreement on the parties. Resultingfinal amount to increase revenues, with implementation of resulting rates will be effective with the first billing cycle of November 2021September 2022 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council wouldwill set a litigated procedural schedule that wouldwill extend the process for City Council approval of disputed rate adjustments into 2022.adjustments.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
COVID-19 Orders
As discussed in the Form 10-K, in JuneMay 2020 the City Council established the City Council Cares Program and directedissued an accounting order authorizing Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per monthestablish a regulatory asset for up to four months, for a maximum of $400 in residential customer bill credits.incremental COVID-19-related expenses. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.
Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021,2022, Entergy New Orleans recordedhad a regulatory asset of $13.8$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.
Hurricane ZetaReliability Investigation
In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. In May 2021, Entergy New Orleans filed an application with the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs, were reasonable and necessary to enable Entergy New Orleans to restore electric service to its customers and Entergy New Orleans’s electric utility infrastructure. Additionally, Entergy New Orleans plans to make a separate filing at an appropriate time to the City Council requesting replenishment of its storm reserves.
Renewable Portfolio Standard Rulemaking
As discussed in the Form 10-K, in MarchApril 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 initiatedadvisors 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 rulemaking proceedingfinancial penalty in the range of $1.5 million to consider whether to establish a renewable portfolio standard.The rulemaking considered, among other issues, whether to adopt a renewable portfolio standard, whether such standard$2 million should be voluntary or mandatory, what kinds of technologies should qualify for inclusionassessed. Entergy New Orleans disagreed with the recommendation and submitted rebuttal testimony and rebuttal comments in the rules, what level, if any, of renewable generation should be required, and whether penalties are an appropriate component of the proposed rules.June 2019. In August 2020November 2019 the City Council advisors issuedpassed a final draftresolution that penalized Entergy New Orleans $1 million for alleged imprudence in the maintenance of the rules for review and comment from the parties before final rules are proposed for consideration by the City Council.its distribution system. In December 2019, Entergy New Orleans filed commentssuit in SeptemberLouisiana 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 2020. In February 2021 the City Council amended the proposed draft rules to exclude beneficial electrificationpassed a resolution and carbon capture from the technologies eligible for credit under the Renewable and Clean Portfolio Standard and opened a 30-day comment period regarding the proposed amendments. Under the rule, however, these technologies can be approved by the City Council as a “qualified measure” on a case-by-case basis. The City Council approved the draft rule, as amended, in May 2021.
Load Shed Investigation
On February 16, 2021, due to high customer demand and limited generation, MISO issued an order requiring load-serving entities throughout its southern region to shed load to protect the integrity of the bulk electric system. Entergy New Orleans was required to shed load of at least 26 MW, but due to certain complications with its automated load shed program and certain load measurement issues, it inadvertently shed approximately 105 MW of load in its service area. The maximum time any customer was without power due to the load shed event was one hour and forty minutes. In late February 2021 the City Council ordered its advisors to conduct an investigation into
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
the load shed event and to issue a report, which was completed and filed in April 2021. The report recommended that the City Council open an additional docket to determine whether any of Entergy New Orleans’s actions were imprudent. In May 2021 the City Council openedestablishing a docket directing its advisorsand procedural schedule with respect to conductsystem resiliency and storm hardening. The docket will identify a prudence investigationplan for storm hardening and determine whether financial and/orresiliency projects with other penalties should be imposed by the City Council.stakeholders. In June 2021,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 the show cause docket that outlined how its response to Winter Storm Uri was reasonable under the circumstances. A City Council decision is expected in the fourth quarter 2021 based on the procedural schedule in the show cause docket. Entergy New Orleans would oppose any attempt to levy a fine under the circumstances presented.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.
Entergy New Orleans, LLC and Subsidiaries
Management's Financial Discussion and Analysis
Critical Accounting Estimates
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, 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.
| | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $159,761 | | | $134,899 | | | $298,909 | | | $258,330 | | Electric | | $224,084 | | | $159,761 | | | $378,730 | | | $298,909 | |
| Natural gas | Natural gas | | 18,979 | | | 12,444 | | | 49,166 | | | 38,315 | | Natural gas | | 30,165 | | | 18,979 | | | 73,791 | | | 49,166 | |
| TOTAL | TOTAL | | 178,740 | | | 147,343 | | | 348,075 | | | 296,645 | | TOTAL | | 254,249 | | | 178,740 | | | 452,521 | | | 348,075 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 34,510 | | | 16,836 | | | 53,522 | | | 44,331 | | Fuel, fuel-related expenses, and gas purchased for resale | | 54,815 | | | 34,510 | | | 98,212 | | | 53,522 | |
| Purchased power | Purchased power | | 57,177 | | | 57,985 | | | 125,847 | | | 114,452 | | Purchased power | | 83,088 | | | 57,177 | | | 139,558 | | | 125,847 | |
| Other operation and maintenance | Other operation and maintenance | | 40,977 | | | 29,126 | | | 79,155 | | | 59,830 | | Other operation and maintenance | | 43,715 | | | 40,977 | | | 77,367 | | | 79,155 | |
| Taxes other than income taxes | Taxes other than income taxes | | 12,294 | | | 15,642 | | | 24,850 | | | 28,848 | | Taxes other than income taxes | | 14,444 | | | 12,294 | | | 28,433 | | | 24,850 | |
| Depreciation and amortization | Depreciation and amortization | | 18,153 | | | 15,626 | | | 36,314 | | | 30,701 | | Depreciation and amortization | | 17,951 | | | 18,153 | | | 37,766 | | | 36,314 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | 2,575 | | | 4,526 | | | 5,705 | | | (1,210) | | Other regulatory charges (credits) - net | | 5,354 | | | 2,575 | | | 9,539 | | | 5,705 | |
| TOTAL | TOTAL | | 165,686 | | | 139,741 | | | 325,393 | | | 276,952 | | TOTAL | | 219,367 | | | 165,686 | | | 390,875 | | | 325,393 | |
| | OPERATING INCOME | OPERATING INCOME | | 13,054 | | | 7,602 | | | 22,682 | | | 19,693 | | OPERATING INCOME | | 34,882 | | | 13,054 | | | 61,646 | | | 22,682 | |
| | OTHER INCOME | OTHER INCOME | | OTHER INCOME | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 376 | | | 2,048 | | | 634 | | | 4,533 | | Allowance for equity funds used during construction | | (449) | | | 376 | | | (80) | | | 634 | |
| Interest and investment income | Interest and investment income | | 5 | | | 43 | | | 14 | | | 96 | | Interest and investment income | | 68 | | | 5 | | | 92 | | | 14 | |
| Miscellaneous - net | Miscellaneous - net | | (204) | | | 168 | | | (506) | | | (570) | | Miscellaneous - net | | 1,221 | | | (204) | | | 950 | | | (506) | |
| TOTAL | TOTAL | | 177 | | | 2,259 | | | 142 | | | 4,059 | | TOTAL | | 840 | | | 177 | | | 962 | | | 142 | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 6,962 | | | 7,635 | | | 13,991 | | | 14,275 | | Interest expense | | 8,698 | | | 6,962 | | | 17,392 | | | 13,991 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (167) | | | (985) | | | (283) | | | (2,180) | | Allowance for borrowed funds used during construction | | 159 | | | (167) | | | (40) | | | (283) | |
| TOTAL | TOTAL | | 6,795 | | | 6,650 | | | 13,708 | | | 12,095 | | TOTAL | | 8,857 | | | 6,795 | | | 17,352 | | | 13,708 | |
| | INCOME BEFORE INCOME TAXES | INCOME BEFORE INCOME TAXES | | 6,436 | | | 3,211 | | | 9,116 | | | 11,657 | | INCOME BEFORE INCOME TAXES | | 26,865 | | | 6,436 | | | 45,256 | | | 9,116 | |
| | Income taxes | Income taxes | | 1,805 | | | (1,718) | | | 2,714 | | | (4,458) | | Income taxes | | 7,319 | | | 1,805 | | | 10,584 | | | 2,714 | |
| | NET INCOME | NET INCOME | | $4,631 | | | $4,929 | | | $6,402 | | | $16,115 | | NET INCOME | | $19,546 | | | $4,631 | | | $34,672 | | | $6,402 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | Net income | | $6,402 | | | $16,115 | | Net income | | $34,672 | | | $6,402 | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | Adjustments to reconcile net income to net cash flow provided by operating activities: | | Adjustments to reconcile net income to net cash flow provided by operating activities: | |
| Depreciation and amortization | Depreciation and amortization | | 36,314 | | | 30,701 | | Depreciation and amortization | | 37,766 | | | 36,314 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 4,907 | | | 1,228 | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 16,265 | | | 4,907 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Receivables | Receivables | | (15,306) | | | 5,255 | | Receivables | | 9,240 | | | (15,306) | |
| Fuel inventory | Fuel inventory | | 725 | | | 1,042 | | Fuel inventory | | (844) | | | 725 | |
| Accounts payable | Accounts payable | | (7,309) | | | (1,725) | | Accounts payable | | 3,909 | | | (7,309) | |
| Taxes accrued | Taxes accrued | | 948 | | | 1,887 | | Taxes accrued | | (2,524) | | | 948 | |
| Interest accrued | Interest accrued | | (1,315) | | | 529 | | Interest accrued | | (361) | | | (1,315) | |
| Deferred fuel costs | Deferred fuel costs | | 4,423 | | | 3,351 | | Deferred fuel costs | | (31,599) | | | 4,423 | |
| Other working capital accounts | Other working capital accounts | | (11,944) | | | (19,793) | | Other working capital accounts | | (9,725) | | | (11,944) | |
| Provisions for estimated losses | Provisions for estimated losses | | (40,152) | | | 1,521 | | Provisions for estimated losses | | 6,319 | | | (40,152) | |
| Other regulatory assets | Other regulatory assets | | 35,038 | | | 3,508 | | Other regulatory assets | | 24,541 | | | 35,038 | |
| Other regulatory liabilities | Other regulatory liabilities | | 4,823 | | | (14,151) | | Other regulatory liabilities | | (15,456) | | | 4,823 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | (7,352) | | | (7,523) | | Pension and other postretirement liabilities | | (4,741) | | | (7,352) | |
| Other assets and liabilities | Other assets and liabilities | | 16,986 | | | 2,715 | | Other assets and liabilities | | (11,839) | | | 16,986 | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 27,188 | | | 24,660 | | Net cash flow provided by operating activities | | 55,623 | | | 27,188 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (94,173) | | | (114,961) | | Construction expenditures | | (115,552) | | | (94,173) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 634 | | | 4,533 | | Allowance for equity funds used during construction | | (80) | | | 634 | |
| Payment for purchase of assets | | 0 | | | (1,584) | | |
| | | Changes in money pool receivable - net | Changes in money pool receivable - net | | 0 | | | (586) | | Changes in money pool receivable - net | | 33,473 | | | — | |
| Receipts from storm reserve escrow account | Receipts from storm reserve escrow account | | 44,200 | | | 0 | | Receipts from storm reserve escrow account | | — | | | 44,200 | |
| Payments to storm reserve escrow account | Payments to storm reserve escrow account | | (7) | | | (405) | | Payments to storm reserve escrow account | | — | | | (7) | |
| Changes in securitization account | Changes in securitization account | | 686 | | | 451 | | Changes in securitization account | | 259 | | | 686 | |
| | Net cash flow used in investing activities | Net cash flow used in investing activities | | (48,660) | | | (112,552) | | Net cash flow used in investing activities | | (81,900) | | | (48,660) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | | 0 | | | 138,939 | | |
| | Retirement of long-term debt | Retirement of long-term debt | | (5,749) | | | (25,616) | | Retirement of long-term debt | | (5,916) | | | (5,749) | |
| | Change in money pool payable - net | | 27,684 | | | 0 | | |
| Changes in money pool payable - net | | Changes in money pool payable - net | | — | | | 27,684 | |
| | Other | Other | | (463) | | | (703) | | Other | | 15,682 | | | (463) | |
| Net cash flow provided by financing activities | Net cash flow provided by financing activities | | 21,472 | | | 112,620 | | Net cash flow provided by financing activities | | 9,766 | | | 21,472 | |
| | Net increase in cash and cash equivalents | | 0 | | | 24,728 | | |
| Net decrease in cash and cash equivalents | | Net decrease in cash and cash equivalents | | (16,511) | | | — | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 26 | | | 6,017 | | Cash and cash equivalents at beginning of period | | 42,862 | | | 26 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $26 | | | $30,745 | | Cash and cash equivalents at end of period | | $26,351 | | | $26 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | |
| Cash paid during the period for: | Cash paid during the period for: | | Cash paid during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $14,684 | | | $13,132 | | Interest - net of amount capitalized | | $17,055 | | | $14,684 | |
| Income taxes | Income taxes | | $324 | | | $3,332 | | Income taxes | | $— | | | $324 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | CURRENT ASSETS | |
| Cash and cash equivalents: | Cash and cash equivalents: | | Cash and cash equivalents: | |
| Cash | Cash | | $26 | | | $26 | | Cash | | $686 | | | $26 | |
| | Temporary cash investments | | Temporary cash investments | | 25,665 | | | 42,836 | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 26 | | | 26 | | Total cash and cash equivalents | | 26,351 | | | 42,862 | |
| Securitization recovery trust account | Securitization recovery trust account | | 2,678 | | | 3,364 | | Securitization recovery trust account | | 1,740 | | | 1,999 | |
| Accounts receivable: | Accounts receivable: | | | Accounts receivable: | | |
| Customer | Customer | | 86,901 | | | 70,694 | | Customer | | 77,869 | | | 69,902 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | (21,132) | | | (17,430) | | Allowance for doubtful accounts | | (6,913) | | | (13,282) | |
| Associated companies | Associated companies | | 1,406 | | | 2,381 | | Associated companies | | 6,489 | | | 74,146 | |
| Other | Other | | 8,944 | | | 4,248 | | Other | | 8,912 | | | 13,668 | |
| Accrued unbilled revenues | Accrued unbilled revenues | | 30,149 | | | 31,069 | | Accrued unbilled revenues | | 40,914 | | | 25,550 | |
| Total accounts receivable | Total accounts receivable | | 106,268 | | | 90,962 | | Total accounts receivable | | 127,271 | | | 169,984 | |
| Deferred fuel costs | Deferred fuel costs | | 0 | | | 2,130 | | Deferred fuel costs | | 23,992 | | | — | |
| Fuel inventory - at average cost | Fuel inventory - at average cost | | 1,253 | | | 1,978 | | Fuel inventory - at average cost | | 3,789 | | | 2,945 | |
| Materials and supplies - at average cost | Materials and supplies - at average cost | | 16,034 | | | 16,550 | | Materials and supplies - at average cost | | 21,623 | | | 19,216 | |
| Prepayments and other | Prepayments and other | | 16,257 | | | 3,715 | | Prepayments and other | | 15,018 | | | 5,428 | |
| TOTAL | TOTAL | | 142,516 | | | 118,725 | | TOTAL | | 219,784 | | | 242,434 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | OTHER PROPERTY AND INVESTMENTS | |
| Non-utility property at cost (less accumulated depreciation) | Non-utility property at cost (less accumulated depreciation) | | 1,016 | | | 1,016 | | Non-utility property at cost (less accumulated depreciation) | | 1,044 | | | 1,016 | |
| Storm reserve escrow account | | 38,846 | | | 83,038 | | |
| | | TOTAL | TOTAL | | 39,862 | | | 84,054 | | TOTAL | | 1,044 | | | 1,016 | |
| | UTILITY PLANT | UTILITY PLANT | | UTILITY PLANT | |
| Electric | Electric | | 1,825,128 | | | 1,821,638 | | Electric | | 1,976,201 | | | 1,976,202 | |
| Natural gas | Natural gas | | 359,759 | | | 348,024 | | Natural gas | | 380,217 | | | 373,983 | |
| Construction work in progress | Construction work in progress | | 29,053 | | | 12,460 | | Construction work in progress | | 32,408 | | | 22,199 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 2,213,940 | | | 2,182,122 | | TOTAL UTILITY PLANT | | 2,388,826 | | | 2,372,384 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 755,956 | | | 740,796 | | Less - accumulated depreciation and amortization | | 798,549 | | | 774,309 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 1,457,984 | | | 1,441,326 | | UTILITY PLANT - NET | | 1,590,277 | | | 1,598,075 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | DEFERRED DEBITS AND OTHER ASSETS | |
| Regulatory assets: | Regulatory assets: | | Regulatory assets: | |
| | Deferred fuel costs | Deferred fuel costs | | 4,080 | | | 4,080 | | Deferred fuel costs | | 4,080 | | | 4,080 | |
| Other regulatory assets (includes securitization property of $30,995 as of June 30, 2021 and $35,559 as of December 31, 2020) | | 231,752 | | | 266,790 | | |
| Other regulatory assets (includes securitization property of $19,906 as of June 30, 2022 and $25,761 as of December 31, 2021) | | 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 | |
| Other | Other | | 32,970 | | | 23,931 | | Other | | 62,756 | | | 56,101 | |
| TOTAL | TOTAL | | 268,802 | | | 294,801 | | TOTAL | | 290,912 | | | 308,798 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $1,909,164 | | | $1,938,906 | | TOTAL ASSETS | | $2,102,017 | | | $2,150,323 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | CURRENT LIABILITIES | |
| Currently maturing long-term debt | Currently maturing long-term debt | | $70,000 | | | $0 | | Currently maturing long-term debt | | $70,000 | | | $— | |
| Payable due to associated company | Payable due to associated company | | 1,618 | | | 1,618 | | Payable due to associated company | | 1,326 | | | 1,326 | |
| Accounts payable: | Accounts payable: | | Accounts payable: | |
| Associated companies | Associated companies | | 77,066 | | | 54,234 | | Associated companies | | 51,740 | | | 45,057 | |
| Other | Other | | 34,389 | | | 60,766 | | Other | | 66,467 | | | 146,921 | |
| Customer deposits | Customer deposits | | 27,313 | | | 27,912 | | Customer deposits | | 30,425 | | | 28,539 | |
| Taxes accrued | Taxes accrued | | 5,648 | | | 4,700 | | Taxes accrued | | 1,861 | | | 4,385 | |
| Interest accrued | Interest accrued | | 6,780 | | | 8,095 | | Interest accrued | | 7,630 | | | 7,991 | |
| Deferred fuel costs | Deferred fuel costs | | 2,293 | | | 0 | | Deferred fuel costs | | — | | | 7,607 | |
| Current portion of unprotected excess accumulated deferred income taxes | Current portion of unprotected excess accumulated deferred income taxes | | 3,295 | | | 3,296 | | Current portion of unprotected excess accumulated deferred income taxes | | — | | | 1,906 | |
| Other | Other | | 6,279 | | | 5,462 | | Other | | 6,706 | | | 6,204 | |
| TOTAL | TOTAL | | 234,681 | | | 166,083 | | TOTAL | | 236,155 | | | 249,936 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | NON-CURRENT LIABILITIES | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 343,485 | | | 338,714 | | Accumulated deferred income taxes and taxes accrued | | 382,567 | | | 365,384 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 16,067 | | | 16,095 | | Accumulated deferred investment tax credits | | 16,287 | | | 16,306 | |
| Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 54,637 | | | 55,675 | | Regulatory liability for income taxes - net | | 38,809 | | | 40,589 | |
| Asset retirement cost liabilities | Asset retirement cost liabilities | | 3,898 | | | 3,768 | | Asset retirement cost liabilities | | — | | | 4,032 | |
| Accumulated provisions | Accumulated provisions | | 49,746 | | | 89,898 | | Accumulated provisions | | 12,648 | | | 6,329 | |
| | Long-term debt (includes securitization bonds of $35,664 as of June 30, 2021 and $41,291 as of December 31, 2020) | | 554,341 | | | 629,704 | | |
| Long-term debt (includes securitization bonds of $23,866 as of June 30, 2022 and $29,661 as of December 31, 2021) | | 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 company | Long-term payable due to associated company | | 10,911 | | | 10,911 | | Long-term payable due to associated company | | 9,585 | | | 9,585 | |
| Other | Other | | 28,079 | | | 21,141 | | Other | | 30,675 | | | 42,193 | |
| TOTAL | TOTAL | | 1,061,164 | | | 1,165,906 | | TOTAL | | 1,192,475 | | | 1,261,672 | |
| | Commitments and Contingencies | Commitments and Contingencies | | Commitments and Contingencies | |
| | EQUITY | EQUITY | | EQUITY | |
| Member's equity | Member's equity | | 613,319 | | | 606,917 | | Member's equity | | 673,387 | | | 638,715 | |
| TOTAL | TOTAL | | 613,319 | | | 606,917 | | TOTAL | | 673,387 | | | 638,715 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $1,909,164 | | | $1,938,906 | | TOTAL LIABILITIES AND EQUITY | | $2,102,017 | | | $2,150,323 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | | | | |
| ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY |
For the Three and Six Months Ended June 30, 20212022 and 20202021 |
| (Unaudited) |
| |
| | |
| | Member's Equity |
| | (In Thousands) |
| |
Balance at December 31, 2019 | $497,579 | |
| |
Net income | 11,186 | |
| |
Balance at March 31, 2020 | 508,765 | |
| |
Net income | 4,929 | |
| |
Balance at June 30, 2020 | $513,694 | |
| |
| |
| |
| |
| |
| |
| Balance at December 31, 2020 | $606,917 | |
| |
| Net income | 1,771 | |
| |
| Balance at March 31, 2021 | 608,688 | |
| |
| Net income | 4,631 | |
| |
| Balance at June 30, 2021 | $613,319 | |
| |
| |
| |
| |
| |
| |
| Balance at December 31, 2021 | $638,715 | |
| |
| Net income | 15,126 | |
| |
| Balance at March 31, 2022 | 653,841 | |
| |
| Net income | 19,546 | |
| |
| Balance at June 30, 2022 | $673,387 | |
| |
| |
| |
| |
| |
| See Notes to Financial Statements. | |
ENTERGY TEXAS, INC. AND SUBSIDIARIES
MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS
The COVID-19 Pandemic
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.
Hurricane Laura and Hurricane Delta
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura and Hurricane Delta” in the Form 10-K for a discussion of Hurricane Laura and Hurricane Delta, which caused significant damage to portions of Entergy Texas’s service territory. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas.
Winter Storm Uri
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Texas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Texas were approximately $185 million in February 2021 compared to approximately $50 million in February 2020. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Texas.
Results of Operations
Net Income
Second Quarter 20212022 Compared to Second Quarter 2020
Net income decreased $2.1 million primarily due to higher other operation and maintenance expenses, higher depreciation and amortization expenses, lower other income, and lower volume/weather. The decrease was partially offset by higher retail electric price.
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Net income increased $15.3$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 and higher volume/weather.price. The increase was partially offset by higher depreciation and amortization expenses lowerand 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 a higher effective tax rate.depreciation and amortization expenses.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Operating Revenues
Second Quarter 20212022 Compared to Second Quarter 20202021
Following is an analysis of the change in operating revenues comparing the second quarter 20212022 to the second quarter 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $372.2430.4 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 32.364.1 | |
| Volume/weather | 40.4 | |
| System restoration carrying costs | 21.7 | |
| Retail electric price | 31.88.0 | |
Volume/weather | (5.9) | |
20212022 operating revenues | $430.4564.6 | |
Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.
The retail electric price variance is primarily due to the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.
The volume/weather variance is primarily due to a decrease in usage during the unbilled sales period, partially offset by an increase in commercialweather-adjusted residential usage,resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage.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 iswas primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries,cogeneration customers and an increase in demand from cogeneration customers. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS -expansion projects and existing customers, both primarily in the transportation industry. The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.increase
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
in commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in second quarter 2021.
Billed
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, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 1,318 | | | 1,386 | | | (5) | | Residential | 1,760 | | | 1,486 | | | 18 | |
| Commercial | Commercial | 1,085 | | | 1,033 | | | 5 | | Commercial | 1,231 | | | 1,101 | | | 12 | |
| Industrial | Industrial | 2,213 | | | 2,013 | | | 10 | | Industrial | 2,489 | | | 2,182 | | | 14 | |
| Governmental | Governmental | 61 | | | 62 | | | (2) | | Governmental | 67 | | | 59 | | | 14 | |
| Total retail | Total retail | 4,677 | | | 4,494 | | | 4 | | Total retail | 5,547 | | | 4,828 | | | 15 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Associated companies | Associated companies | 363 | | | 320 | | | 13 | | Associated companies | 89 | | | 363 | | | (75) | |
| Non-associated companies | Non-associated companies | 291 | | | 225 | | | 29 | | Non-associated companies | 161 | | | 291 | | | (45) | |
| Total | Total | 5,331 | | | 5,039 | | | 6 | | Total | 5,797 | | | 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, 20212022 Compared to Six Months Ended June 30, 20202021
Following is an analysis of the change in operating revenues comparing the six months ended June 30, 20212022 to the six months ended June 30, 2020:2021:
| | | | | |
| Amount |
| (In Millions) |
20202021 operating revenues | $711.5910.7 | |
| Fuel, rider, and other revenues that do not significantly affect net income | 136.835.7 | |
| Volume/weather | 40.5 | |
| Retail electric price | 50.528.5 | |
Volume/weatherSystem restoration carrying costs | 11.921.7 | |
20212022 operating revenues | $910.71,037.1 | |
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
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
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 the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increaseto:
•increases in the transmission cost recovery factor rider effective March 2021 and March 2022;
•an increase in the distribution cost recovery factor rider effective MarchJanuary 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.
The volume/weather variance is primarily dueSystem 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 an increasethe financial statements herein for a discussion of 427 GWh, or 5%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from cogeneration customers.securitization.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
BilledTotal electric energy sales for Entergy Texas for the six months ended June 30, 20212022 and 20202021 are as follows:
| | | 2021 | | 2020 | | % Change | | 2022 | | 2021 | | % Change |
| | (GWh) | | | | (GWh) | | |
| Residential | Residential | 2,857 | | | 2,712 | | | 5 | | Residential | 3,220 | | | 2,880 | | | 12 | |
| Commercial | Commercial | 2,085 | | | 2,033 | | | 3 | | Commercial | 2,290 | | | 2,105 | | | 9 | |
| Industrial | Industrial | 4,141 | | | 3,909 | | | 6 | | Industrial | 4,753 | | | 4,145 | | | 15 | |
| Governmental | Governmental | 124 | | | 126 | | | (2) | | Governmental | 131 | | | 121 | | | 8 | |
| Total retail | Total retail | 9,207 | | | 8,780 | | | 5 | | Total retail | 10,394 | | | 9,251 | | | 12 | |
| Sales for resale: | Sales for resale: | | Sales for resale: | |
| Associated companies | Associated companies | 659 | | | 564 | | | 17 | | Associated companies | 279 | | | 659 | | | (58) | |
| Non-associated companies | Non-associated companies | 633 | | | 310 | | | 104 | | Non-associated companies | 305 | | | 633 | | | (52) | |
| Total | Total | 10,499 | | | 9,654 | | | 9 | | Total | 10,978 | | | 10,543 | | | 4 | |
See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Other Income Statement Variances
Second Quarter 20212022 Compared to Second Quarter 20202021
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 $5.1$5 million in non-nuclear generation expenses primarily due to higher expenses associated with the MontgomeryHardin County Power Station,Peaking Facility, which began commercial operationwas purchased in JanuaryJune 2021, and a higher scope of work performed during plant outages in 20212022 as compared to the same period in 2020;2021;
•an increase of $1.1$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 amountdeployment of transmission costs allocated by MISO;advanced metering systems;
•an increase of $1.0$1.8 million in information technologycustomer service center support costs primarily due to higher contract costs and higher costs associated with system maintenance;
•an increase of $0.8 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives;costs; and
•an increase of $0.8 million in vegetation maintenance costs.several individually insignificant items.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.
Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.
Interest expense increased primarily due to a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020
Other operation and maintenance expenses increased primarily due to:
•an increase of $6.3 million in non-nuclear generation expenses primarily due to higher long-term service agreement expenses and other expenses associated with the Montgomery County Power Station, which began commercial operation in January 2021;
•an increase of $2.1 million in customer service costs primarily due to an increase in contract work in 2021 as compared to the same period in 2020;
•an increase of $1.4 million as a result of the amount of transmission costs allocated by MISO;
•an increase of $1.3 million in vegetation maintenance costs; and
•an increase of $1.2 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.
Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.
Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.
Interest expense increased primarily due to a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.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 was 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 differencedifferences 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.
The effective income tax rate was 5.2% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, book and tax differences related to the allowance for equity funds used during construction, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.
The effective income tax rate was (2.1%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, permanent differences related to income tax deductions for stock-based compensation, book and tax differences related to the allowance for equity funds used during construction, and certain book and tax differences related to utility plant items. 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 of178
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $248,596 | | | $12,929 | | Cash and cash equivalents at beginning of period | $28 | | | $248,596 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 119,535 | | | 170,548 | | Operating activities | 171,727 | | | 119,535 | |
| Investing activities | Investing activities | (350,305) | | | (464,795) | | Investing activities | (326,373) | | | (350,305) | |
| Financing activities | Financing activities | (17,801) | | | 323,557 | | Financing activities | 177,193 | | | (17,801) | |
| Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | (248,571) | | | 29,310 | | Net increase (decrease) in cash and cash equivalents | 22,547 | | | (248,571) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $25 | | | $42,239 | | Cash and cash equivalents at end of period | $22,575 | | | $25 | |
Operating Activities
Net cash flow provided by operating activities decreased $51increased $52.2 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•the timing of payments to increased fuel costs as vendors;
•higher collections from customers; and
•a result of Winter Storm Uri and an increasedecrease of approximately $22$22.5 million in storm spending in 2021,2022, primarily due to Hurricane Laura, and Hurricane Delta, restoration efforts. See “and Winter Storm Uri restoration efforts in 2021.
” above for discussion
The increase was partially offset by the timing of the incrementalrecovery of fuel and purchased power costs incurred.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. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts.
Investing Activities
Net cash flow used in investing activities decreased $114.5$23.9 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•a decrease of $98.3$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 higher spendinga lower scope of work on projects performed in 2020 on the Montgomery County Power Station project;2022 as compared to 2021; and
•a decrease of $69.3$22.5 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 20212022 as compared to 2020;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. See Note 14 to the financial statements herein for further discussion of the transaction.million; and
The decrease was partially offset by:
•an increase of $73.7 million in distribution construction expenditures primarily due to storm spending in 2021, partially offset by lower spending in 2021 on advanced metering infrastructure. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts; and
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
•the purchasecash collateral of the Hardin County Peaking Facility$30 million posted in June 2021 for approximately $36.7 million. See Note 142022 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.support Entergy Texas’s obligations to MISO.
Financing Activities
Entergy Texas’s financing activities used $17.8provided $177.2 million of cash for the six months ended June 30, 20212022 compared to providing $323.6using $17.8 million for the six months ended June 30, 20202021 primarily due to the following activity:
•the issuance of $175$290.85 million of 3.55% Series mortgagesenior secured system restoration bonds in March 2020;
•April 2022, as discussed below, and the repayment, prior to maturity, of $125 million of 2.55% Series mortgage bonds in May 2021;
•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 as compared to a capital contribution of $175 million received from Entergy Corporation in March 2020 in anticipation of upcoming expenditures, including Montgomery County Power Station; and
•money pool activity.expenditures.
IncreasesDecreases in Entergy Texas’s payable to the money pool are a sourceuse of cash flow, and Entergy Texas’s payable to the money pool increaseddecreased 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 decreaseincrease in the debt to capital ratio is primarily due to the repaymentissuance of long-term debt in 2021 and the $85 million capital contribution received2022, partially offset by an increase in equity resulting from Entergy Corporation in April 2021.retained earnings.
| | | June 30,
2021 | | December 31,
2020 | | June 30,
2022 | | December 31,
2021 |
| Debt to capital | Debt to capital | 49.9 | % | | 53.7 | % | Debt to capital | 49.9 | % | | 48.7 | % |
| Effect of excluding the securitization bonds | Effect of excluding the securitization bonds | (0.8 | %) | | (1.3 | %) | Effect of excluding the securitization bonds | (3.2 | %) | | (0.5 | %) |
| Debt to capital, excluding securitization bonds (a) | Debt to capital, excluding securitization bonds (a) | 49.1 | % | | 52.4 | % | Debt to capital, excluding securitization bonds (a) | 46.7 | % | | 48.2 | % |
| Effect of subtracting cash | Effect of subtracting cash | — | % | | (2.7 | %) | Effect of subtracting cash | (0.2 | %) | | — | % |
| Net debt to net capital, excluding securitization bonds (a) | Net debt to net capital, excluding securitization bonds (a) | 49.1 | % | | 49.7 | % | 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.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Uses and Sources of Capital
See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Texas’s uses and sources of capital. Following are updates to information provided in the Form 10-K.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
Following are the current annual amounts of Entergy Texas’s planned construction and other capital investments.
| | | | | | | | | | | | | | | | | |
| | 2022 | | 2023 | | 2024 |
| | (In Millions) |
| Planned construction and capital investment: | | | | | |
| Generation | $110 | | | $270 | | | $515 | |
| Transmission | 115 | | | 175 | | | 185 | |
| Distribution | 260 | | | 390 | | | 355 | |
| Utility Support | 70 | | | 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,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31,
2019 |
| (In Thousands) |
| ($63,437) | | $4,601 | | $7,802 | | $11,181 |
| | | | | | | | | | | | | | | | | | | | |
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 2026.2027. 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, 2021,2022, there were no cash borrowings and $1.3$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, 2021, $18.22022, $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.
LibertyOrange County Solar FacilityAdvanced Power Station
InAs discussed in the Form 10-K, in September 2020,2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquireconstruct, own, and operate the 100Orange County Advanced Power Station, a new 1,215 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisitioncombined-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 facility through a tax equity partnership isestimated 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 public interest.future. In its preliminary order,December 2021 the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s usereferred the proceeding to the State Office of a tax equity partnership is in the public interest.Administrative Hearings. In March 20212022 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
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
project. In April 2022, Entergy Texas filed rebuttal testimony addressing and rebutting these various arguments. Also in April 2021. A2022 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 April 2021. Post-hearingJune 2022 and reply briefing was completedpost-hearing briefs were submitted in May 2021. In July 2021 the presiding administrative law judges issued2022. The initial fixed pricing window closed in July 2022, and Entergy Texas intends to obtain a proposal for decision recommending that thenew fixed pricing option prior to PUCT deny the certification requested in the application. This proposal for decision is subjectapproval and issuance of notice to change based on exceptions filed by the parties. Once it isproceed. A final it will be presented to the PUCT, which may adopt or modify it. A decisionorder by the PUCT is expected in September 2021. Closing, subjectthe 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 occurbe in 2023.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
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
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 October 2020,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 $26.3$40.2 million annually, or $6.8$13.9 million in incremental annual revenues beyond Entergy Texas’s then-effectivecurrently effective DCRF rider based on its capital invested in distribution between JanuarySeptember 1, 2020 and August 31, 2020.June 30, 2021. In FebruarySeptember 2021 the administrative law judge withPUCT referred the proceeding to the State Office of Administrative Hearings approved Entergy Texas’s
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
agreed motion for interim rates, which went into effectHearings. A procedural schedule was established with a hearing scheduled in MarchDecember 2021. In MarchDecember 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.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 May 2021March 2022 the PUCT issued an order approving the settlement.
Transmission Cost Recovery Factor (TCRF) Rider
As discussed in the Form 10-K, in October 2020,2021, 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 $51$66.1 million annually, or $31.6$15.1 million in incremental annual revenues beyond EntergyEnergy Texas’s then-effectivecurrently effective TCRF rider based on its capital invested in transmission between September 1, 2020 and July 1, 201931, 2021 and August 31, 2020. A procedural schedule was established with a hearing scheduledchanges in March 2021.approved transmission charges. In January 2022 the PUCT referred the proceeding to the State Office of Administrative Hearings. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 20212022 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in2022. In February 2022 the proceeding. In March 2021 the administrative law judgeALJ granted the motion for interim rates, admitted evidence, and remanded thisthe case to the PUCT for consideration of a final order at a future open meeting. In June 20212022 the PUCT issued an order approving the settlement.
Fuel and purchased power recoveryGeneration Cost Recovery Rider
In February 2021,As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to implementestablish a fuel refund forgeneration cost recovery rider to begin recovering a cumulative over-recoveryreturn of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issueand on its generation capital investment in the refund over the period of MarchMontgomery County Power Station through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how31, 2020, which was approved by the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position.PUCT on an interim basis in January 2021. In March 2021, Entergy Texas withdrewfiled 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
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
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 implementalign the fuel refund.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 is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistentfiled on behalf of the parties an unopposed motion, which motion was granted by the ALJ with the requirementsState 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 PUCT’s rules.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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021,2022, Entergy Texas recordedhad a regulatory asset of $14.2$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.
Generation Cost Recovery RiderGreen Pricing Option Tariffs
As discussed in the Form 10-K, in October 2020,In January 2022, Entergy Texas filed an application requesting approval to establish a generationimplement 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 recovery riderallocation between the rate tiers of Rider SVRO and committed to collaborating with and considering the input of customers to develop an initial annual revenue requirementasset-backed green tariff program. This matter is awaiting placement on an open meeting agenda for PUCT consideration of approximately $91 million to begin recovering a return ofthe settlement.
Fuel and on its capital investment in the Montgomery County Power Station through August 31, 2020. purchased power recovery
In December 2020,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 supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costsresolving all issues in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021,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
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge.
In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order granting Entergy Texas’s motion, approving interim rates effective with the application. In August 2021, Entergy Texas filed an update application to recover its actual investment infirst billing cycle of September 2022, and remanding the acquisition of the Hardin County Peaking Facility. See Note 14case to the financial statements hereinPUCT for further discussion of the Hardin County Peaking Facility purchase.
Storm Cost Filings
In August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of the system restoration costs that are the subject of the April 2021 application. As stated in the July 2021 application, Entergy Texas also plans to seek a separate financing order, in a separate application and docket, under the newly-enacted Subchapter J of Chapter 36 of the Public Utility Regulatory Act, titled “Lower-Cost Financing Mechanism for Securitization for Recovery of System Restoration Costs.” However, the ability to timely utilize that mechanism for securitization of the system restoration costs that are approved for recovery is dependent on certain events outside of Entergy Texas’s control, which may necessitate utilizing the traditional structure for securitization of the system restoration costs as may be approved for recovery in the proceeding initiated in July 2021. In either event, only one financing order would ultimately be utilized for the securitization of system restoration costs approved for recovery by the PUCT. A procedural schedule was established with a hearing on the merits in September 2021.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.
Entergy Texas, Inc. and Subsidiaries
Management's Financial Discussion and Analysis
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.
| | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES |
| CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS | CONSOLIDATED INCOME STATEMENTS |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $430,434 | | | $372,194 | | | $910,654 | | | $711,530 | | Electric | | $564,591 | | | $430,434 | | | $1,037,073 | | | $910,654 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 64,031 | | | 47,790 | | | 176,427 | | | 89,136 | | Fuel, fuel-related expenses, and gas purchased for resale | | 60,855 | | | 64,031 | | | 134,775 | | | 176,427 | |
| | Purchased power | Purchased power | | 128,699 | | | 124,351 | | | 270,061 | | | 244,142 | | Purchased power | | 195,016 | | | 128,699 | | | 356,106 | | | 270,061 | |
| Other operation and maintenance | Other operation and maintenance | | 70,815 | | | 60,527 | | | 133,770 | | | 119,460 | | Other operation and maintenance | | 72,589 | | | 70,815 | | | 147,566 | | | 133,770 | |
| | Taxes other than income taxes | Taxes other than income taxes | | 20,671 | | | 20,524 | | | 42,546 | | | 39,796 | | Taxes other than income taxes | | 23,482 | | | 20,671 | | | 43,931 | | | 42,546 | |
| Depreciation and amortization | Depreciation and amortization | | 53,587 | | | 43,835 | | | 104,523 | | | 86,401 | | Depreciation and amortization | | 57,248 | | | 53,587 | | | 113,309 | | | 104,523 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | 25,253 | | | 18,724 | | | 41,093 | | | 40,092 | | Other regulatory charges (credits) - net | | 22,399 | | | 25,253 | | | 35,845 | | | 41,093 | |
| TOTAL | TOTAL | | 363,056 | | | 315,751 | | | 768,420 | | | 619,027 | | TOTAL | | 431,589 | | | 363,056 | | | 831,532 | | | 768,420 | |
| | OPERATING INCOME | OPERATING INCOME | | 67,378 | | | 56,443 | | | 142,234 | | | 92,503 | | OPERATING INCOME | | 133,002 | | | 67,378 | | | 205,541 | | | 142,234 | |
| | OTHER INCOME | OTHER INCOME | | OTHER INCOME | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 2,670 | | | 11,601 | | | 5,115 | | | 22,242 | | Allowance for equity funds used during construction | | 3,163 | | | 2,670 | | | 5,759 | | | 5,115 | |
| Interest and investment income | Interest and investment income | | 204 | | | 343 | | | 428 | | | 772 | | Interest and investment income | | 347 | | | 204 | | | 535 | | | 428 | |
| Miscellaneous - net | Miscellaneous - net | | (527) | | | (791) | | | (950) | | | (1,137) | | Miscellaneous - net | | (409) | | | (527) | | | (102) | | | (950) | |
| TOTAL | TOTAL | | 2,347 | | | 11,153 | | | 4,593 | | | 21,877 | | TOTAL | | 3,101 | | | 2,347 | | | 6,192 | | | 4,593 | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 21,899 | | | 23,137 | | | 44,937 | | | 45,995 | | Interest expense | | 23,101 | | | 21,899 | | | 44,013 | | | 44,937 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (1,075) | | | (4,985) | | | (2,059) | | | (9,558) | | Allowance for borrowed funds used during construction | | (1,067) | | | (1,075) | | | (1,932) | | | (2,059) | |
| TOTAL | TOTAL | | 20,824 | | | 18,152 | | | 42,878 | | | 36,437 | | TOTAL | | 22,034 | | | 20,824 | | | 42,081 | | | 42,878 | |
| | INCOME BEFORE INCOME TAXES | INCOME BEFORE INCOME TAXES | | 48,901 | | | 49,444 | | | 103,949 | | | 77,943 | | INCOME BEFORE INCOME TAXES | | 114,069 | | | 48,901 | | | 169,652 | | | 103,949 | |
| | Income taxes | Income taxes | | 4,111 | | | 2,576 | | | 9,101 | | | (1,632) | | Income taxes | | 16,584 | | | 4,111 | | | 21,764 | | | 9,101 | |
| | NET INCOME | NET INCOME | | 44,790 | | | 46,868 | | | 94,848 | | | 79,575 | | NET INCOME | | 97,485 | | | 44,790 | | | 147,888 | | | 94,848 | |
| | Preferred dividend requirements | Preferred dividend requirements | | 471 | | | 471 | | | 941 | | | 941 | | Preferred dividend requirements | | 518 | | | 471 | | | 1,036 | | | 941 | |
| | EARNINGS APPLICABLE TO COMMON STOCK | EARNINGS APPLICABLE TO COMMON STOCK | | $44,319 | | | $46,397 | | | $93,907 | | | $78,634 | | EARNINGS APPLICABLE TO COMMON STOCK | | $96,967 | | | $44,319 | | | $146,852 | | | $93,907 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS | CONSOLIDATED STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | Net income | | $94,848 | | | $79,575 | | Net income | | $147,888 | | | $94,848 | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | Adjustments to reconcile net income to net cash flow provided by operating activities: | | Adjustments to reconcile net income to net cash flow provided by operating activities: | |
| Depreciation and amortization | Depreciation and amortization | | 104,523 | | | 86,401 | | Depreciation and amortization | | 113,309 | | | 104,523 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 5,237 | | | 9,470 | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | 24,421 | | | 5,237 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Receivables | Receivables | | (33,522) | | | (20,524) | | Receivables | | (55,237) | | | (33,522) | |
| Fuel inventory | Fuel inventory | | 3,606 | | | 1,222 | | Fuel inventory | | 16,888 | | | 3,606 | |
| Accounts payable | Accounts payable | | 1,530 | | | (3,543) | | Accounts payable | | 79,801 | | | 1,530 | |
| Taxes accrued | Taxes accrued | | (4,057) | | | (11,390) | | Taxes accrued | | (7,158) | | | (4,057) | |
| Interest accrued | Interest accrued | | (1,072) | | | 359 | | Interest accrued | | 1,923 | | | (1,072) | |
| Deferred fuel costs | Deferred fuel costs | | (72,537) | | | 17,226 | | Deferred fuel costs | | (141,192) | | | (72,537) | |
| Other working capital accounts | Other working capital accounts | | (3,285) | | | 9,928 | | Other working capital accounts | | 2,388 | | | (3,285) | |
| Provisions for estimated losses | Provisions for estimated losses | | 314 | | | 91 | | Provisions for estimated losses | | (10) | | | 314 | |
| Other regulatory assets | Other regulatory assets | | 43,619 | | | 50,347 | | Other regulatory assets | | (143,294) | | | 43,619 | |
| Other regulatory liabilities | Other regulatory liabilities | | (2,036) | | | (23,947) | | Other regulatory liabilities | | (14,444) | | | (2,036) | |
| Storm restoration costs approved for securitization recognized as regulatory asset | | Storm restoration costs approved for securitization recognized as regulatory asset | | 153,383 | | | — | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | (11,050) | | | (13,825) | | Pension and other postretirement liabilities | | (9,475) | | | (11,050) | |
| Other assets and liabilities | Other assets and liabilities | | (6,583) | | | (10,842) | | Other assets and liabilities | | 2,536 | | | (6,583) | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 119,535 | | | 170,548 | | Net cash flow provided by operating activities | | 171,727 | | | 119,535 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (401,362) | | | (495,560) | | Construction expenditures | | (304,702) | | | (401,362) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 5,115 | | | 22,242 | | Allowance for equity funds used during construction | | 5,759 | | | 5,115 | |
| Proceeds from sale of assets | Proceeds from sale of assets | | 67,920 | | | 0 | | Proceeds from sale of assets | | — | | | 67,920 | |
| | Payment for purchase of assets | Payment for purchase of assets | | (36,534) | | | (4,931) | | Payment for purchase of assets | | — | | | (36,534) | |
| Litigation proceeds from settlement agreement | | Litigation proceeds from settlement agreement | | 4,134 | | | — | |
| Changes in money pool receivable - net | Changes in money pool receivable - net | | 4,601 | | | 3,379 | | Changes in money pool receivable - net | | (1,643) | | | 4,601 | |
| Changes in securitization account | Changes in securitization account | | 9,955 | | | 10,075 | | Changes in securitization account | | 79 | | | 9,955 | |
| Increase in other investments | | Increase in other investments | | (30,000) | | | — | |
| | Net cash flow used in investing activities | Net cash flow used in investing activities | | (350,305) | | | (464,795) | | Net cash flow used in investing activities | | (326,373) | | | (350,305) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | | 0 | | | 194,256 | | Proceeds from the issuance of long-term debt | | 286,842 | | | — | |
| Retirement of long-term debt | Retirement of long-term debt | | (170,429) | | | (43,376) | | Retirement of long-term debt | | (29,064) | | | (170,429) | |
| Capital contribution from parent | Capital contribution from parent | | 85,000 | | | 175,000 | | Capital contribution from parent | | — | | | 85,000 | |
| | Change in money pool payable - net | | 63,437 | | | 0 | | |
| Changes in money pool payable - net | | Changes in money pool payable - net | | (79,594) | | | 63,437 | |
| | Preferred stock dividends paid | Preferred stock dividends paid | | (941) | | | (1,124) | | Preferred stock dividends paid | | (1,024) | | | (941) | |
| Other | Other | | 5,132 | | | (1,199) | | Other | | 33 | | | 5,132 | |
| Net cash flow provided by (used in) financing activities | Net cash flow provided by (used in) financing activities | | (17,801) | | | 323,557 | | Net cash flow provided by (used in) financing activities | | 177,193 | | | (17,801) | |
| | Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | | (248,571) | | | 29,310 | | Net increase (decrease) in cash and cash equivalents | | 22,547 | | | (248,571) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 248,596 | | | 12,929 | | Cash and cash equivalents at beginning of period | | 28 | | | 248,596 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $25 | | | $42,239 | | Cash and cash equivalents at end of period | | $22,575 | | | $25 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | |
| Cash paid during the period for: | Cash paid during the period for: | | Cash paid during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $44,760 | | | $44,683 | | Interest - net of amount capitalized | | $40,816 | | | $44,760 | |
| Income taxes | Income taxes | | $9,710 | | | $4,031 | | Income taxes | | $1,085 | | | $9,710 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
|
| | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | CURRENT ASSETS | |
| Cash and cash equivalents: | Cash and cash equivalents: | | Cash and cash equivalents: | |
| Cash | Cash | | $25 | | | $26 | | Cash | | $8,224 | | | $28 | |
| Temporary cash investments | Temporary cash investments | | 0 | | | 248,570 | | Temporary cash investments | | 14,351 | | | — | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 25 | | | 248,596 | | Total cash and cash equivalents | | 22,575 | | | 28 | |
| Securitization recovery trust account | Securitization recovery trust account | | 26,278 | | | 36,233 | | Securitization recovery trust account | | 26,551 | | | 26,629 | |
| Accounts receivable: | Accounts receivable: | | Accounts receivable: | |
| Customer | Customer | | 111,163 | | | 103,221 | | Customer | | 122,672 | | | 83,797 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | (12,223) | | | (16,810) | | Allowance for doubtful accounts | | (2,591) | | | (5,814) | |
| Associated companies | Associated companies | | 17,494 | | | 18,892 | | Associated companies | | 19,898 | | | 31,720 | |
| Other | Other | | 17,328 | | | 11,780 | | Other | | 18,714 | | | 13,404 | |
| Accrued unbilled revenues | Accrued unbilled revenues | | 68,654 | | | 56,411 | | Accrued unbilled revenues | | 83,535 | | | 62,241 | |
| Total accounts receivable | Total accounts receivable | | 202,416 | | | 173,494 | | Total accounts receivable | | 242,228 | | | 185,348 | |
| | Deferred fuel costs | | Deferred fuel costs | | 189,472 | | | 48,280 | |
| Fuel inventory - at average cost | Fuel inventory - at average cost | | 49,925 | | | 53,531 | | Fuel inventory - at average cost | | 25,824 | | | 42,712 | |
| Materials and supplies - at average cost | Materials and supplies - at average cost | | 63,417 | | | 56,227 | | Materials and supplies - at average cost | | 77,731 | | | 72,884 | |
| | Prepayments and other | Prepayments and other | | 15,055 | | | 20,165 | | Prepayments and other | | 43,807 | | | 17,515 | |
| TOTAL | TOTAL | | 357,116 | | | 588,246 | | TOTAL | | 628,188 | | | 393,396 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | OTHER PROPERTY AND INVESTMENTS | |
| Investments in affiliates - at equity | Investments in affiliates - at equity | | 324 | | | 349 | | Investments in affiliates - at equity | | 275 | | | 300 | |
| Non-utility property - at cost (less accumulated depreciation) | Non-utility property - at cost (less accumulated depreciation) | | 376 | | | 376 | | Non-utility property - at cost (less accumulated depreciation) | | 376 | | | 376 | |
| Other | Other | | 17,744 | | | 19,889 | | Other | | 17,938 | | | 18,128 | |
| TOTAL | TOTAL | | 18,444 | | | 20,614 | | TOTAL | | 18,589 | | | 18,804 | |
| | UTILITY PLANT | UTILITY PLANT | | UTILITY PLANT | |
| Electric | Electric | | 6,918,133 | | | 6,007,687 | | Electric | | 7,165,752 | | | 7,181,567 | |
| Construction work in progress | Construction work in progress | | 181,473 | | | 879,908 | | Construction work in progress | | 245,788 | | | 183,965 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 7,099,606 | | | 6,887,595 | | TOTAL UTILITY PLANT | | 7,411,540 | | | 7,365,532 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 1,981,761 | | | 1,864,494 | | Less - accumulated depreciation and amortization | | 2,090,728 | | | 2,049,750 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 5,117,845 | | | 5,023,101 | | UTILITY PLANT - NET | | 5,320,812 | | | 5,315,782 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | DEFERRED DEBITS AND OTHER ASSETS | |
| Regulatory assets: | Regulatory assets: | | Regulatory assets: | |
| | Other regulatory assets (includes securitization property of $52,330 as of June 30, 2021 and $78,590 as of December 31, 2020) | | 481,094 | | | 524,713 | | |
| Other regulatory assets (includes securitization property of $283,503 as of June 30, 2022 and $23,818 as of December 31, 2021) | | 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 | |
| | Other | Other | | 81,501 | | | 70,397 | | Other | | 123,447 | | | 112,096 | |
| TOTAL | TOTAL | | 562,595 | | | 595,110 | | TOTAL | | 688,074 | | | 533,429 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $6,056,000 | | | $6,227,071 | | TOTAL ASSETS | | $6,655,663 | | | $6,261,411 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | | | | See Notes to Financial Statements. | | | | |
| | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES |
| CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS | CONSOLIDATED BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | CURRENT LIABILITIES | |
| Currently maturing long-term debt | | $75,000 | | | $200,000 | | |
| | Accounts payable: | Accounts payable: | | Accounts payable: | |
| Associated companies | Associated companies | | 110,028 | | | 55,944 | | Associated companies | | $70,373 | | | $142,929 | |
| Other | Other | | 179,398 | | | 350,947 | | Other | | 209,234 | | | 164,981 | |
| Customer deposits | Customer deposits | | 33,437 | | | 36,282 | | Customer deposits | | 37,992 | | | 37,271 | |
| Taxes accrued | Taxes accrued | | 48,381 | | | 52,438 | | Taxes accrued | | 41,860 | | | 49,018 | |
| Interest accrued | Interest accrued | | 19,784 | | | 20,856 | | Interest accrued | | 20,925 | | | 19,002 | |
| Current portion of unprotected excess accumulated deferred income taxes | Current portion of unprotected excess accumulated deferred income taxes | | 29,855 | | | 29,249 | | Current portion of unprotected excess accumulated deferred income taxes | | 12,862 | | | 27,188 | |
| Deferred fuel costs | | 12,819 | | | 85,356 | | |
| | | Other | Other | | 14,303 | | | 12,370 | | Other | | 16,845 | | | 16,120 | |
| TOTAL | TOTAL | | 523,005 | | | 843,442 | | TOTAL | | 410,091 | | | 456,509 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | NON-CURRENT LIABILITIES | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 647,348 | | | 639,422 | | Accumulated deferred income taxes and taxes accrued | | 724,033 | | | 692,496 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 9,634 | | | 9,942 | | Accumulated deferred investment tax credits | | 9,018 | | | 9,325 | |
| Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 157,086 | | | 175,594 | | Regulatory liability for income taxes - net | | 135,550 | | | 144,145 | |
| Other regulatory liabilities | Other regulatory liabilities | | 48,163 | | | 32,297 | | Other regulatory liabilities | | 45,537 | | | 37,060 | |
| Asset retirement cost liabilities | Asset retirement cost liabilities | | 8,288 | | | 8,063 | | Asset retirement cost liabilities | | 8,758 | | | 8,520 | |
| Accumulated provisions | Accumulated provisions | | 8,696 | | | 8,382 | | Accumulated provisions | | 8,232 | | | 8,242 | |
| | Long-term debt (includes securitization bonds of $77,908 as of June 30, 2021 and $123,066 as of December 31, 2020) | | 2,248,879 | | | 2,293,708 | | |
| Long-term debt (includes securitization bonds of $312,129 as of June 30, 2022 and $53,979 as of December 31, 2021) | | 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 | |
| Other | Other | | 68,416 | | | 58,643 | | Other | | 71,512 | | | 67,760 | |
| TOTAL | TOTAL | | 3,196,510 | | | 3,226,051 | | TOTAL | | 3,615,514 | | | 3,321,696 | |
| | Commitments and Contingencies | Commitments and Contingencies | | Commitments and Contingencies | |
| | EQUITY | EQUITY | | EQUITY | |
| Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2021 and 2020 | | 49,452 | | | 49,452 | | |
| Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2022 and 2021 | | 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 capital | Paid-in capital | | 1,040,162 | | | 955,162 | | Paid-in capital | | 1,050,125 | | | 1,050,125 | |
| Retained earnings | Retained earnings | | 1,211,871 | | | 1,117,964 | | Retained earnings | | 1,491,731 | | | 1,344,879 | |
| Total common shareholder's equity | Total common shareholder's equity | | 2,301,485 | | | 2,122,578 | | Total common shareholder's equity | | 2,591,308 | | | 2,444,456 | |
| Preferred stock without sinking fund | Preferred stock without sinking fund | | 35,000 | | | 35,000 | | Preferred stock without sinking fund | | 38,750 | | | 38,750 | |
| TOTAL | TOTAL | | 2,336,485 | | | 2,157,578 | | TOTAL | | 2,630,058 | | | 2,483,206 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $6,056,000 | | | $6,227,071 | | TOTAL LIABILITIES AND EQUITY | | $6,655,663 | | | $6,261,411 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES | ENTERGY TEXAS, INC. AND SUBSIDIARIES |
| CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY | CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY | CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | Common Equity | | |
| Preferred Stock | | Common
Stock | | Paid-in
Capital | | Retained
Earnings | | Total | |
| (In Thousands) | |
| | Balance at December 31, 2019 | $35,000 | | | $49,452 | | | $780,182 | | | $934,773 | | | $1,799,407 | | |
| | Net income | 0 | | | 0 | | | 0 | | | 32,707 | | | 32,707 | | |
| Capital contribution from parent | 0 | | | 0 | | | 175,000 | | | 0 | | | 175,000 | | |
| Preferred stock dividends | 0 | | | 0 | | | 0 | | | (470) | | | (470) | | |
| Balance at March 31, 2020 | 35,000 | | | 49,452 | | | 955,182 | | | 967,010 | | | 2,006,644 | | |
| | Net income | 0 | | | 0 | | | 0 | | | 46,868 | | | 46,868 | | |
| Preferred stock dividends | 0 | | | 0 | | | 0 | | | (471) | | | (471) | | |
| Other | 0 | | | 0 | | | (10) | | | 0 | | | (10) | | |
| Balance at June 30, 2020 | $35,000 | | | $49,452 | | | $955,172 | | | $1,013,407 | | | $2,053,031 | | |
| | | | Common Equity | |
| | | Preferred Stock | | Common
Stock | | Paid-in
Capital | | Retained
Earnings | | Total |
| | | (In Thousands) |
| | Balance at December 31, 2020 | Balance at December 31, 2020 | $35,000 | | | $49,452 | | | $955,162 | | | $1,117,964 | | | $2,157,578 | | Balance at December 31, 2020 | $35,000 | | | $49,452 | | | $955,162 | | | $1,117,964 | | | $2,157,578 | |
| | Net income | Net income | 0 | | | 0 | | | 0 | | | 50,058 | | | 50,058 | | Net income | — | | | — | | | — | | | 50,058 | | | 50,058 | |
| | Preferred stock dividends | Preferred stock dividends | 0 | | | 0 | | | 0 | | | (470) | | | (470) | | Preferred stock dividends | — | | | — | | | — | | | (470) | | | (470) | |
| Balance at March 31, 2021 | Balance at March 31, 2021 | 35,000 | | | 49,452 | | | 955,162 | | | 1,167,552 | | | 2,207,166 | | Balance at March 31, 2021 | 35,000 | | | 49,452 | | | 955,162 | | | 1,167,552 | | | 2,207,166 | |
| | Net income | Net income | 0 | | | 0 | | | 0 | | | 44,790 | | | 44,790 | | Net income | — | | | — | | | — | | | 44,790 | | | 44,790 | |
| Capital contribution from parent | Capital contribution from parent | 0 | | | 0 | | | 85,000 | | | 0 | | | 85,000 | | Capital contribution from parent | — | | | — | | | 85,000 | | | — | | | 85,000 | |
| Preferred stock dividends | Preferred stock dividends | 0 | | | 0 | | | 0 | | | (471) | | | (471) | | Preferred stock dividends | — | | | — | | | — | | | (471) | | | (471) | |
| | Balance at June 30, 2021 | Balance at June 30, 2021 | $35,000 | | | $49,452 | | | $1,040,162 | | | $1,211,871 | | | $2,336,485 | | Balance at June 30, 2021 | $35,000 | | | $49,452 | | | $1,040,162 | | | $1,211,871 | | | $2,336,485 | |
| | | | | | Balance at December 31, 2021 | | Balance at December 31, 2021 | $38,750 | | | $49,452 | | | $1,050,125 | | | $1,344,879 | | | $2,483,206 | |
| | Net income | | Net income | — | | | — | | | — | | | 50,403 | | | 50,403 | |
| | Preferred stock dividends | | Preferred stock dividends | — | | | — | | | — | | | (518) | | | (518) | |
| Balance at March 31, 2022 | | Balance at March 31, 2022 | 38,750 | | | 49,452 | | | 1,050,125 | | | 1,394,764 | | | 2,533,091 | |
| | Net income | | Net income | — | | | — | | | — | | | 97,485 | | | 97,485 | |
| | Preferred stock dividends | | Preferred stock dividends | — | | | — | | | — | | | (518) | | | (518) | |
| | Balance at June 30, 2022 | | Balance at June 30, 2022 | $38,750 | | | $49,452 | | | $1,050,125 | | | $1,491,731 | | | $2,630,058 | |
| | | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
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 20212022 Compared to Second Quarter 20202021
Net income increased $1.3System Energy experienced a net loss of $380.1 million in the second quarter 2022 primarily due to changesa regulatory charge of $551 million ($413 million net-of-tax) recorded in rate base.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, 20212022 Compared to Six Months Ended June 30, 20202021
NetSystem Energy experienced a net loss of $348.7 million in the six months ended June 30, 2022 compared to net income decreased $3.3of $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 basebase. See Note 2 to the financial statements herein for discussion of the partial settlement agreement and a decrease in the allowance for equity funds used during construction resulting from higher spending in 2020 including the scheduled 2020 Grand Gulf refueling outage.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.
The effective income tax rate was 20.5% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes.
The effective income tax rate was 18.4% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
Liquidity and Capital Resources
Cash Flow
Cash flows for the six months ended June 30, 20212022 and 20202021 were as follows:
| | | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | $242,469 | | | $68,534 | | Cash and cash equivalents at beginning of period | $89,201 | | | $242,469 | |
| | Cash flow provided by (used in): | | |
| Net cash provided by (used in): | | Net cash provided by (used in): | |
| Operating activities | Operating activities | 44,451 | | | 84,736 | | Operating activities | 82,645 | | | 44,451 | |
| Investing activities | Investing activities | (86,677) | | | (157,713) | | Investing activities | (94,001) | | | (86,677) | |
| Financing activities | Financing activities | (81,021) | | | 4,550 | | Financing activities | 56,880 | | | (81,021) | |
| Net decrease in cash and cash equivalents | (123,247) | | | (68,427) | | |
| Net increase (decrease) in cash and cash equivalents | | Net increase (decrease) in cash and cash equivalents | 45,524 | | | (123,247) | |
| | Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $119,222 | | | $107 | | Cash and cash equivalents at end of period | $134,725 | | | $119,222 | |
Operating Activities
Net cash flow provided by operating activities decreased $40.3increased $38.2 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to income tax payments of $39.1 million in 2021, and timing of collections of receivables, and timing of payments to vendors, partially offset by a decreasean increase in spending of $35.2$33.5 million on nuclear refueling outages in 20212022 as compared to the same period in 2020 and timing of payments to vendors.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 decreased $71increased $7.3 million for the six months ended June 30, 20212022 compared to the six months ended June 30, 20202021 primarily due to:
•a decreasean increase of $111$61.6 million in nuclear construction expenditures as a result ofdue to increased spending on various nuclear projects in 2020 on Grand Gulf outage projects and upgrades;2022; and
•an increase of $67.2$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 decreaseincrease was partially offset by money pool activity.
IncreasesDecreases in System Energy’s receivable from the money pool are a usesource of cash flow and System Energy’s receivable from the money pool increaseddecreased 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 compared to decreasing by $59.3 million for the six months ended June 30, 2020.2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
Financing Activities
System Energy’s financing activities usedprovided $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 compared to providing $4.6 million of cash for the six months ended June 30, 2020 primarily due to the following activity: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;
•money pool activity; and
•a decrease of $33.7$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.
Increasesstructure and in System Energy’s payable toanticipation of the money pool is a source of cash flow, and System Energy’s payable tosettlement with the money pool increased by $15.8 million for the six months ended June 30, 2020.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 decreaseincrease in the debt to capital ratio is primarily due to the net repayment of long-term debtloss in 2021.2022.
| | | | | | | | | | | |
| | June 30,
2021 | | December 31,
2020 |
| Debt to capital | 40.4 | % | | 42.7 | % |
| Effect of subtracting cash | (4.1 | %) | | (8.5 | %) |
| Net debt to net capital | 36.3 | % | | 34.2 | % |
| | | | | | | | | | | |
| | June 30,
2022 | | December 31,
2021 |
| Debt to capital | 51.8 | % | | 40.4 | % |
| Effect of subtracting cash | (4.6 | %) | | (3.0 | %) |
| Net debt to net capital | 47.2 | % | | 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 or (payables to) the money pool were as follows:
| | | | | | | | | | | | | | | | | | | | |
June 30,
2021 | | December 31,
2020 | | June 30,
2020 | | December 31, 2019 |
| (In Thousands) |
| $60,111 | | $4,004 | | ($15,774) | | $59,298 |
| | | | | | | | | | | | | | | | | | | | |
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.
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in June 2024.2025. As of June 30, 2021, $45.72022, $93.8 million in loans were outstanding under the
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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 May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.
In March 2021 the FERC ALJ issued an initial decision.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 $59$61 million, which includes interest through June 30, 2021,2022, and the estimated resulting annual rate reduction would be approximately $46approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021.
The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue
As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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, 2021,2022 is approximately $422 million, plus interest, which is approximately $119approximately $139 million through June 30 2021., 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, 2021.2022.
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.
Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.
In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.
LPSC Authorization of Additional Complaints
As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigation of rates charged by System
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
Energy. The LPSC directive authorizes its staff to file complaints at the FERC “necessary to address these rate issues, to request a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”
Unit Power Sales Agreement Complaint
The first of the additional complaints was filed by the LPSC, the APSC, the MPSC, and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishingestablishing 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 is currently in abeyance.was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.
Grand Gulf Prudence Complaint
The second of the additional complaints was filed at the FERC in MarchIn November 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations,filed direct testimony and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provideorder refunds for full cost recovery only if certain performance indicators are metprior periods and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modificationsprospective amendments to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants andAgreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy duringshould not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the period from March through July 2021.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
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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.
System Energy Resources, Inc.
Management's Financial Discussion and Analysis
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. Following is an update to that discussion
NRC Reactor Oversight Process
As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs.
In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.
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.
| | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. |
| INCOME STATEMENTS | |
| For the Three and Six Months Ended June 30, 2021 and 2020 | |
| STATEMENTS OF OPERATIONS | | STATEMENTS OF OPERATIONS |
| For the Three and Six Months Ended June 30, 2022 and 2021 | | For the Three and Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | | Three Months Ended | | Six Months Ended | | Three Months Ended | | Six Months Ended |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2022 | | 2021 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) | | (In Thousands) | | (In Thousands) |
| OPERATING REVENUES | OPERATING REVENUES | | OPERATING REVENUES | |
| Electric | Electric | | $161,313 | | | $126,049 | | | $279,059 | | | $256,713 | | Electric | | $163,872 | | | $161,313 | | | $305,248 | | | $279,059 | |
| | OPERATING EXPENSES | OPERATING EXPENSES | | OPERATING EXPENSES | |
| Operation and Maintenance: | Operation and Maintenance: | | Operation and Maintenance: | |
| Fuel, fuel-related expenses, and gas purchased for resale | Fuel, fuel-related expenses, and gas purchased for resale | | 14,073 | | | 6,008 | | | 30,932 | | | 19,151 | | Fuel, fuel-related expenses, and gas purchased for resale | | 11,610 | | | 14,073 | | | 19,533 | | | 30,932 | |
| Nuclear refueling outage expenses | Nuclear refueling outage expenses | | 6,792 | | | 5,666 | | | 13,510 | | | 13,938 | | Nuclear refueling outage expenses | | 5,320 | | | 6,792 | | | 11,247 | | | 13,510 | |
| Other operation and maintenance | Other operation and maintenance | | 58,047 | | | 42,802 | | | 100,007 | | | 83,273 | | Other operation and maintenance | | 54,685 | | | 58,047 | | | 98,589 | | | 100,007 | |
| Decommissioning | Decommissioning | | 9,625 | | | 9,248 | | | 19,154 | | | 18,405 | | Decommissioning | | 10,016 | | | 9,625 | | | 19,933 | | | 19,154 | |
| Taxes other than income taxes | Taxes other than income taxes | | 6,968 | | | 7,105 | | | 13,793 | | | 15,078 | | Taxes other than income taxes | | 7,150 | | | 6,968 | | | 15,001 | | | 13,793 | |
| Depreciation and amortization | Depreciation and amortization | | 25,768 | | | 27,501 | | | 53,962 | | | 54,400 | | Depreciation and amortization | | 37,777 | | | 25,768 | | | 67,700 | | | 53,962 | |
| Other regulatory charges (credits) - net | Other regulatory charges (credits) - net | | (17,550) | | | (3,517) | | | (6,000) | | | (14,077) | | Other regulatory charges (credits) - net | | 527,515 | | | (17,550) | | | 518,991 | | | (6,000) | |
| TOTAL | TOTAL | | 103,723 | | | 94,813 | | | 225,358 | | | 190,168 | | TOTAL | | 654,073 | | | 103,723 | | | 750,994 | | | 225,358 | |
| | OPERATING INCOME | | 57,590 | | | 31,236 | | | 53,701 | | | 66,545 | | |
| OPERATING INCOME (LOSS) | | OPERATING INCOME (LOSS) | | (490,201) | | | 57,590 | | | (445,746) | | | 53,701 | |
| | OTHER INCOME (DEDUCTIONS) | OTHER INCOME (DEDUCTIONS) | | OTHER INCOME (DEDUCTIONS) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 1,355 | | | 3,200 | | | 2,466 | | | 6,784 | | Allowance for equity funds used during construction | | 2,581 | | | 1,355 | | | 4,628 | | | 2,466 | |
| Interest and investment income | Interest and investment income | | (2,410) | | | 12,108 | | | 25,032 | | | 17,446 | | Interest and investment income | | (8,959) | | | (2,410) | | | (3,727) | | | 25,032 | |
| Miscellaneous - net | Miscellaneous - net | | (7,886) | | | (2,157) | | | (9,910) | | | (4,617) | | Miscellaneous - net | | (2,741) | | | (7,886) | | | (4,380) | | | (9,910) | |
| TOTAL | TOTAL | | (8,941) | | | 13,151 | | | 17,588 | | | 19,613 | | TOTAL | | (9,119) | | | (8,941) | | | (3,479) | | | 17,588 | |
| | INTEREST EXPENSE | INTEREST EXPENSE | | INTEREST EXPENSE | |
| Interest expense | Interest expense | | 9,579 | | | 8,534 | | | 19,114 | | | 17,074 | | Interest expense | | 9,112 | | | 9,579 | | | 18,593 | | | 19,114 | |
| Allowance for borrowed funds used during construction | Allowance for borrowed funds used during construction | | (229) | | | (634) | | | (417) | | | (1,345) | | Allowance for borrowed funds used during construction | | (409) | | | (229) | | | (736) | | | (417) | |
| TOTAL | TOTAL | | 9,350 | | | 7,900 | | | 18,697 | | | 15,729 | | TOTAL | | 8,703 | | | 9,350 | | | 17,857 | | | 18,697 | |
| | INCOME BEFORE INCOME TAXES | | 39,299 | | | 36,487 | | | 52,592 | | | 70,429 | | |
| INCOME (LOSS) BEFORE INCOME TAXES | | INCOME (LOSS) BEFORE INCOME TAXES | | (508,023) | | | 39,299 | | | (467,082) | | | 52,592 | |
| | Income taxes | Income taxes | | 8,969 | | | 7,496 | | | (1,602) | | | 12,925 | | Income taxes | | (127,875) | | | 8,969 | | | (118,366) | | | (1,602) | |
| | NET INCOME | | $30,330 | | | $28,991 | | | $54,194 | | | $57,504 | | |
| NET INCOME (LOSS) | | NET INCOME (LOSS) | | ($380,148) | | | $30,330 | | | ($348,716) | | | $54,194 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. |
| STATEMENTS OF CASH FLOWS | STATEMENTS OF CASH FLOWS | STATEMENTS OF CASH FLOWS |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| OPERATING ACTIVITIES | OPERATING ACTIVITIES | | OPERATING ACTIVITIES | |
| Net income | | $54,194 | | | $57,504 | | |
| Adjustments to reconcile net income to net cash flow provided by operating activities: | | | |
| Net income (loss) | | Net income (loss) | | ($348,716) | | | $54,194 | |
| Adjustments to reconcile net income (loss) to net cash flow provided by operating activities: | | Adjustments to reconcile net income (loss) to net cash flow provided by operating activities: | | |
| Depreciation, amortization, and decommissioning, including nuclear fuel amortization | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 101,640 | | | 88,343 | | Depreciation, amortization, and decommissioning, including nuclear fuel amortization | | 104,296 | | | 101,640 | |
| Deferred income taxes, investment tax credits, and non-current taxes accrued | Deferred income taxes, investment tax credits, and non-current taxes accrued | | (3,052) | | | 517 | | Deferred income taxes, investment tax credits, and non-current taxes accrued | | (124,202) | | | (3,052) | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Receivables | Receivables | | (15,877) | | | 18,213 | | Receivables | | (14,753) | | | (15,877) | |
| Accounts payable | Accounts payable | | (3,449) | | | (18,591) | | Accounts payable | | (27,368) | | | (3,449) | |
| Taxes accrued | Taxes accrued | | (27,698) | | | 6,020 | | Taxes accrued | | (2,664) | | | (27,698) | |
| Interest accrued | Interest accrued | | (1,102) | | | (12) | | Interest accrued | | (247) | | | (1,102) | |
| Other working capital accounts | Other working capital accounts | | 442 | | | (41,850) | | Other working capital accounts | | (41,234) | | | 442 | |
| Other regulatory assets | Other regulatory assets | | 60,949 | | | (21,072) | | Other regulatory assets | | (22,768) | | | 60,949 | |
| Other regulatory liabilities | Other regulatory liabilities | | 49,033 | | | (21,672) | | Other regulatory liabilities | | 338,280 | | | 49,033 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | (12,243) | | | (5,354) | | Pension and other postretirement liabilities | | (7,494) | | | (12,243) | |
| Other assets and liabilities | Other assets and liabilities | | (158,386) | | | 22,690 | | Other assets and liabilities | | 229,515 | | | (158,386) | |
| Net cash flow provided by operating activities | Net cash flow provided by operating activities | | 44,451 | | | 84,736 | | Net cash flow provided by operating activities | | 82,645 | | | 44,451 | |
| | INVESTING ACTIVITIES | INVESTING ACTIVITIES | | INVESTING ACTIVITIES | |
| Construction expenditures | Construction expenditures | | (38,268) | | | (147,889) | | Construction expenditures | | (100,953) | | | (38,268) | |
| Allowance for equity funds used during construction | Allowance for equity funds used during construction | | 2,466 | | | 6,784 | | Allowance for equity funds used during construction | | 4,628 | | | 2,466 | |
| Nuclear fuel purchases | Nuclear fuel purchases | | (11,039) | | | (75,024) | | Nuclear fuel purchases | | (77,704) | | | (11,039) | |
| Proceeds from the sale of nuclear fuel | Proceeds from the sale of nuclear fuel | | 12,754 | | | 9,573 | | Proceeds from the sale of nuclear fuel | | 18,845 | | | 12,754 | |
| | Proceeds from nuclear decommissioning trust fund sales | Proceeds from nuclear decommissioning trust fund sales | | 418,042 | | | 275,563 | | Proceeds from nuclear decommissioning trust fund sales | | 177,584 | | | 418,042 | |
| Investment in nuclear decommissioning trust funds | Investment in nuclear decommissioning trust funds | | (414,525) | | | (286,018) | | Investment in nuclear decommissioning trust funds | | (176,735) | | | (414,525) | |
| Changes in money pool receivable - net | Changes in money pool receivable - net | | (56,107) | | | 59,298 | | Changes in money pool receivable - net | | 60,334 | | | (56,107) | |
| | Net cash flow used in investing activities | Net cash flow used in investing activities | | (86,677) | | | (157,713) | | Net cash flow used in investing activities | | (94,001) | | | (86,677) | |
| | FINANCING ACTIVITIES | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | | 453,981 | | | 482,533 | | Proceeds from the issuance of long-term debt | | 556,696 | | | 453,981 | |
| Retirement of long-term debt | Retirement of long-term debt | | (509,002) | | | (434,104) | | Retirement of long-term debt | | (499,816) | | | (509,002) | |
| | Change in money pool payable - net | | 0 | | | 15,774 | | |
| | | Common stock dividends and distributions paid | Common stock dividends and distributions paid | | (26,000) | | | (59,653) | | Common stock dividends and distributions paid | | — | | | (26,000) | |
| | Net cash flow provided by (used in) financing activities | Net cash flow provided by (used in) financing activities | | (81,021) | | | 4,550 | | Net cash flow provided by (used in) financing activities | | 56,880 | | | (81,021) | |
| | Net decrease in cash and cash equivalents | | (123,247) | | | (68,427) | | |
| Net increase (decrease) in cash and cash equivalents | | Net increase (decrease) in cash and cash equivalents | | 45,524 | | | (123,247) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | | 242,469 | | | 68,534 | | Cash and cash equivalents at beginning of period | | 89,201 | | | 242,469 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | | $119,222 | | | $107 | | Cash and cash equivalents at end of period | | $134,725 | | | $119,222 | |
| | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | |
| Cash paid (received) during the period for: | | |
| Cash paid during the period for: | | Cash paid during the period for: | |
| Interest - net of amount capitalized | Interest - net of amount capitalized | | $29,231 | | | $8,589 | | Interest - net of amount capitalized | | $19,454 | | | $29,231 | |
| Income taxes | Income taxes | | $39,085 | | | ($4,000) | | Income taxes | | $— | | | $39,085 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. |
| BALANCE SHEETS | BALANCE SHEETS | BALANCE SHEETS |
| ASSETS | ASSETS | ASSETS |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT ASSETS | CURRENT ASSETS | | CURRENT ASSETS | |
| Cash and cash equivalents: | Cash and cash equivalents: | | Cash and cash equivalents: | |
| Cash | Cash | | $139 | | | $26,086 | | Cash | | $77 | | | $87 | |
| Temporary cash investments | Temporary cash investments | | 119,083 | | | 216,383 | | Temporary cash investments | | 134,648 | | | 89,114 | |
| Total cash and cash equivalents | Total cash and cash equivalents | | 119,222 | | | 242,469 | | Total cash and cash equivalents | | 134,725 | | | 89,201 | |
| Accounts receivable: | Accounts receivable: | | | | | Accounts receivable: | | | | |
| Associated companies | Associated companies | | 127,194 | | | 57,743 | | Associated companies | | 75,557 | | | 118,977 | |
| Other | Other | | 5,083 | | | 2,550 | | Other | | 4,842 | | | 7,003 | |
| Total accounts receivable | Total accounts receivable | | 132,277 | | | 60,293 | | Total accounts receivable | | 80,399 | | | 125,980 | |
| | Materials and supplies - at average cost | Materials and supplies - at average cost | | 136,428 | | | 123,006 | | Materials and supplies - at average cost | | 127,154 | | | 127,093 | |
| Deferred nuclear refueling outage costs | Deferred nuclear refueling outage costs | | 21,314 | | | 34,459 | | Deferred nuclear refueling outage costs | | 47,789 | | | 10,123 | |
| | Prepayments and other | Prepayments and other | | 6,143 | | | 6,864 | | Prepayments and other | | 5,376 | | | 1,870 | |
| TOTAL | TOTAL | | 415,384 | | | 467,091 | | TOTAL | | 395,443 | | | 354,267 | |
| | OTHER PROPERTY AND INVESTMENTS | OTHER PROPERTY AND INVESTMENTS | | OTHER PROPERTY AND INVESTMENTS | |
| Decommissioning trust funds | Decommissioning trust funds | | 1,312,525 | | | 1,215,868 | | Decommissioning trust funds | | 1,138,811 | | | 1,385,254 | |
| TOTAL | TOTAL | | 1,312,525 | | | 1,215,868 | | TOTAL | | 1,138,811 | | | 1,385,254 | |
| | UTILITY PLANT | UTILITY PLANT | | UTILITY PLANT | |
| Electric | Electric | | 5,321,319 | | | 5,309,458 | | Electric | | 5,442,584 | | | 5,362,494 | |
| | Construction work in progress | Construction work in progress | | 75,019 | | | 59,831 | | Construction work in progress | | 79,596 | | | 97,968 | |
| Nuclear fuel | Nuclear fuel | | 133,364 | | | 175,005 | | Nuclear fuel | | 193,253 | | | 171,438 | |
| TOTAL UTILITY PLANT | TOTAL UTILITY PLANT | | 5,529,702 | | | 5,544,294 | | TOTAL UTILITY PLANT | | 5,715,433 | | | 5,631,900 | |
| Less - accumulated depreciation and amortization | Less - accumulated depreciation and amortization | | 3,351,715 | | | 3,355,367 | | Less - accumulated depreciation and amortization | | 3,423,021 | | | 3,396,136 | |
| UTILITY PLANT - NET | UTILITY PLANT - NET | | 2,177,987 | | | 2,188,927 | | UTILITY PLANT - NET | | 2,292,412 | | | 2,235,764 | |
| | DEFERRED DEBITS AND OTHER ASSETS | DEFERRED DEBITS AND OTHER ASSETS | | DEFERRED DEBITS AND OTHER ASSETS | |
| Regulatory assets: | Regulatory assets: | | Regulatory assets: | |
| | Other regulatory assets | Other regulatory assets | | 478,014 | | | 538,963 | | Other regulatory assets | | 418,314 | | | 395,546 | |
| | Other | Other | | 2,277 | | | 3,119 | | Other | | 1,781 | | | 1,793 | |
| TOTAL | TOTAL | | 480,291 | | | 542,082 | | TOTAL | | 420,095 | | | 397,339 | |
| | TOTAL ASSETS | TOTAL ASSETS | | $4,386,187 | | | $4,413,968 | | TOTAL ASSETS | | $4,246,761 | | | $4,372,624 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. |
| BALANCE SHEETS | BALANCE SHEETS | BALANCE SHEETS |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY |
| June 30, 2021 and December 31, 2020 | |
| June 30, 2022 and December 31, 2021 | | June 30, 2022 and December 31, 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In Thousands) | | (In Thousands) |
| CURRENT LIABILITIES | CURRENT LIABILITIES | | CURRENT LIABILITIES | |
| Currently maturing long-term debt | Currently maturing long-term debt | | $50,324 | | | $100,015 | | Currently maturing long-term debt | | $250,030 | | | $50,329 | |
| | Accounts payable: | Accounts payable: | | Accounts payable: | |
| Associated companies | Associated companies | | 18,825 | | | 15,309 | | Associated companies | | 13,797 | | | 23,682 | |
| Other | Other | | 38,862 | | | 41,313 | | Other | | 50,948 | | | 62,573 | |
| Taxes accrued | Taxes accrued | | 55,279 | | | 82,977 | | Taxes accrued | | 30,254 | | | 32,918 | |
| | Interest accrued | Interest accrued | | 11,620 | | | 12,722 | | Interest accrued | | 11,467 | | | 11,714 | |
| | Other | Other | | 4,246 | | | 4,248 | | Other | | 4,100 | | | 4,101 | |
| TOTAL | TOTAL | | 179,156 | | | 256,584 | | TOTAL | | 360,596 | | | 185,317 | |
| | NON-CURRENT LIABILITIES | NON-CURRENT LIABILITIES | | NON-CURRENT LIABILITIES | |
| Accumulated deferred income taxes and taxes accrued | Accumulated deferred income taxes and taxes accrued | | 349,912 | | | 359,835 | | Accumulated deferred income taxes and taxes accrued | | 260,035 | | | 382,931 | |
| Accumulated deferred investment tax credits | Accumulated deferred investment tax credits | | 43,643 | | | 38,902 | | Accumulated deferred investment tax credits | | 42,364 | | | 43,003 | |
| Regulatory liability for income taxes - net | Regulatory liability for income taxes - net | | 132,794 | | | 151,829 | | Regulatory liability for income taxes - net | | 109,309 | | | 113,165 | |
| Other regulatory liabilities | Other regulatory liabilities | | 733,464 | | | 665,396 | | Other regulatory liabilities | | 1,087,080 | | | 744,944 | |
| Decommissioning | Decommissioning | | 988,064 | | | 968,910 | | Decommissioning | | 1,027,536 | | | 1,007,603 | |
| Pension and other postretirement liabilities | Pension and other postretirement liabilities | | 113,169 | | | 125,412 | | Pension and other postretirement liabilities | | 68,610 | | | 76,104 | |
| Long-term debt | Long-term debt | | 700,615 | | | 705,259 | | Long-term debt | | 548,585 | | | 690,967 | |
| Other | Other | | 36,630 | | | 61,295 | | Other | | 2 | | | 37,230 | |
| TOTAL | TOTAL | | 3,098,291 | | | 3,076,838 | | TOTAL | | 3,143,521 | | | 3,095,947 | |
| | Commitments and Contingencies | Commitments and Contingencies | | Commitments and Contingencies | |
| | COMMON EQUITY | COMMON EQUITY | | COMMON EQUITY | |
| Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2021 and 2020 | | 951,850 | | | 951,850 | | |
| Retained earnings | | 156,890 | | | 128,696 | | |
| Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2022 and 2021 | | 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) | | Retained earnings (accumulated deficit) | | (209,206) | | | 139,510 | |
| TOTAL | TOTAL | | 1,108,740 | | | 1,080,546 | | TOTAL | | 742,644 | | | 1,091,360 | |
| | TOTAL LIABILITIES AND EQUITY | TOTAL LIABILITIES AND EQUITY | | $4,386,187 | | | $4,413,968 | | TOTAL LIABILITIES AND EQUITY | | $4,246,761 | | | $4,372,624 | |
| | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
| | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. | SYSTEM ENERGY RESOURCES, INC. |
| STATEMENTS OF CHANGES IN COMMON EQUITY | STATEMENTS OF CHANGES IN COMMON EQUITY | STATEMENTS OF CHANGES IN COMMON EQUITY |
| For the Six Months Ended June 30, 2021 and 2020 | |
| For the Six Months Ended June 30, 2022 and 2021 | | For the Six Months Ended June 30, 2022 and 2021 |
| (Unaudited) | (Unaudited) | (Unaudited) |
| | Common Equity | | |
| Common
Stock | | Retained
Earnings | | Total | |
| (In Thousands) | |
| | Balance at December 31, 2019 | $601,850 | | | $110,218 | | | $712,068 | | |
| | Net income | 0 | | | 28,513 | | | 28,513 | | |
| Common stock dividends and distributions | 0 | | | (13,653) | | | (13,653) | | |
| Balance at March 31, 2020 | 601,850 | | | 125,078 | | | 726,928 | | |
| | Net income | 0 | | | 28,991 | | | 28,991 | | |
| Common stock dividends and distributions | 0 | | | (46,000) | | | (46,000) | | |
| Balance at June 30, 2020 | $601,850 | | | $108,069 | | | $709,919 | | |
| | | | | Common Equity | |
| | | Common
Stock | | Retained
Earnings (Accumulated Deficit) | | Total |
| | | (In Thousands) |
| | Balance at December 31, 2020 | Balance at December 31, 2020 | $951,850 | | | $128,696 | | | $1,080,546 | | Balance at December 31, 2020 | $951,850 | | | $128,696 | | | $1,080,546 | |
| | Net income | Net income | 0 | | | 23,864 | | | 23,864 | | Net income | — | | | 23,864 | | | 23,864 | |
| Common stock dividends and distributions | Common stock dividends and distributions | 0 | | | (21,000) | | | (21,000) | | Common stock dividends and distributions | — | | | (21,000) | | | (21,000) | |
| Balance at March 31, 2021 | Balance at March 31, 2021 | 951,850 | | | 131,560 | | | 1,083,410 | | Balance at March 31, 2021 | 951,850 | | | 131,560 | | | 1,083,410 | |
| | Net income | Net income | 0 | | | 30,330 | | | 30,330 | | Net income | — | | | 30,330 | | | 30,330 | |
| Common stock dividends and distributions | Common stock dividends and distributions | 0 | | | (5,000) | | | (5,000) | | Common stock dividends and distributions | — | | | (5,000) | | | (5,000) | |
| Balance at June 30, 2021 | Balance at June 30, 2021 | $951,850 | | | $156,890 | | | $1,108,740 | | Balance at June 30, 2021 | $951,850 | | | $156,890 | | | $1,108,740 | |
| | | | | Balance at December 31, 2021 | | Balance at December 31, 2021 | $951,850 | | | $139,510 | | | $1,091,360 | |
| | Net income | | Net income | — | | | 31,432 | | | 31,432 | |
| | Balance at March 31, 2022 | | Balance at March 31, 2022 | 951,850 | | | 170,942 | | | 1,122,792 | |
| | Net loss | | Net loss | — | | | (380,148) | | | (380,148) | |
| | Balance at June 30, 2022 | | Balance at June 30, 2022 | $951,850 | | | ($209,206) | | | $742,644 | |
| | | See Notes to Financial Statements. | See Notes to Financial Statements. | | See Notes to Financial Statements. | |
ENTERGY CORPORATION AND SUBSIDIARIES
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy. Also see 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 FactorsRISK FACTORS”" in the Form 10-K, which could materially affect Entergy’sEntergy's and its Registrant Subsidiaries’Subsidiaries' business, financial condition, or future results. The information set forth in this report, including the risk factor presented below, updates and should be read in conjunction with the risk factors and information disclosed in the Form 10-K.In addition, because Entergy cannot predict the ultimate impacts of COVID-19, the actual impacts may also exacerbate other risks discussed in “Item 1A. Risk Factors” in the Form 10-K, any of which could have a material effect on Entergy and its Registrant Subsidiaries.
The impactscompletion of capital projects, including the COVID-19 pandemicconstruction of power generation facilities, and responsive measures taken on Entergy’s and its Utility operating companies’ business,other capital improvements involve substantial risks. Should such efforts be unsuccessful, the financial condition, results of operations, and financial condition are highly uncertain and cannot be predicted.
In December 2019 a novel strainor liquidity of coronavirus was reported to have surfaced in Wuhan, China. Since then, several variants of the COVID-19 virus have spread throughout the world, including the United States. To mitigate the spread of COVID-19, public health officials in the United States have both recommended and mandated wearing of masks and other precautions, including prohibitions on congregating in heavily-populated areas, mandated closure or limitations on the functions of non-essential business, and shelter-in-place orders or similar measures, including throughout Entergy’s service areas. While most of these mitigation measures have been lifted following the wide availability of COVID-19 vaccines, there is a risk that certain of these measures could be reinstated and/or continued, particularly given the recent spread within the Entergy service areas of the delta variant of COVID-19, and that such measures could have an adverse effect on the general economy, Entergy’s customers, and its operations.
Entergy and its Utility operating companies experienced a decline in commercial and industrial sales and an increase in arrearages and bad debt expense due to non-payment by customers, and while much of the commercial and industrial sales have recovered, such increased arrearages and bad debt expense are expected to continue, the extent and duration of which management cannot predict. The Utility operating companies have resumed disconnecting customers for non-payment of bills, but such disconnects could again be suspended at the Utility operating companies should another shelter-in-place order or similar measure occur and their regulators mandate. While they are working with regulators to ensure ultimate recovery for those and other COVID-19 related costs, the amount, method, and timing of such recovery is unknown. Entergy and its Registrant Subsidiaries also could experience, and in some cases have experienced, among other challenges, supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; delays in regulatory proceedings; workforce availability, health or safety issues; increased storm recovery costs; increased cybersecurity risks as a result of many employees telecommuting; volatility in the credit or capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available credit facilities); or other adverse impacts on their ability to execute on business strategies and initiatives.be materially affected.
Although the economy has been recovering, another economic decline could adversely impact Entergy’s and the Utility operating companies’ liquidityability to complete capital projects, including the construction of power generation facilities, or make other capital improvements, in a timely manner and cash flows, including through declining sales, reduced revenues,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 receiptsobtaining permits, shortages in materials and qualified labor, levels of customer payments,public support or increased bad debt expense. The Utility operating companies also may experience regulatory outcomesopposition, suppliers and contractors not performing as expected or required under their contracts and/or experiencing financial problems that require theminhibit their ability to postpone planned investment and otherwise reduce costs due to the impact of the COVID-19 pandemic onfulfill their customers. In addition, if the COVID-19 pandemic creates additional disruptions or turmoilobligations under contracts, changes in the credit or financial markets, or adversely impacts Entergy’s credit metrics or ratings, such developments could adversely affect its abilityscope and timing of projects, poor quality initial cost estimates from contractors, the inability to accessraise 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 continuetariff 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.
meet its liquidity needs or cause a decrease in the value of its defined benefit pension trust funds, as well as its nuclear decommissioning trust funds, all of which are highly uncertain and cannot be predicted.
Entergy cannot predict the extent or duration of the outbreak, the impact of new variants of COVID-19, the timing, availability, distribution or effectiveness of a vaccine, anti-viral or other treatments for COVID-19, governmental responsive measures, or the extent of the effects or ultimate impacts on the global, national or local economy, the capital markets, or its customers, suppliers, operations, financial condition, results of operations, or cash flows.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Issuer Purchases of Equity Securities (a)
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| Period | | Total Number of
Shares Purchased | | Average Price Paid
per Share | | Total Number of
Shares Purchased
as Part of a
Publicly
Announced Plan | | Maximum $
Amount
of Shares that May
Yet be Purchased
Under a Plan (b) |
| | | | | | | | |
4/01/2021-4/2022-4/30/20212022 | | — | | | $— | | | — | | | $350,052,918 | |
5/01/2021-5/2022-5/31/20212022 | | — | | | $— | | | — | | | $350,052,918 | |
6/01/2021-6/2022-6/30/20212022 | | — | | | $— | | | — | | | $350,052,918 | |
| Total | | — | | | $— | | | — | | | |
In accordance with Entergy’s stock-based compensation plans, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock. According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market. Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans. In addition to this authority, the Board has authorized share repurchase programs to enable opportunistic purchases in response to market conditions. In October 2010 the Board granted authority for a $500 million share repurchase program. The amount of share repurchases under these programs may vary as a result of material changes in business results or capital spending or new investment opportunities. In addition, in the first quarter 2021,2022, Entergy withheld 81,43479,738 shares of its common stock at $95.12$110.35 per share, 40,47677,207 shares of its common stock at $95.15$111.16 per share, 36,80435,940 shares of its common stock at $94.75$111.77 per share, 36,3471,219 shares of its common stock at $95.33$109.01 per share, 1,188577 shares of its common stock at $91.16$106.62 per share, 853232 shares of its common stock at $96.47$110.77 per share, 71987 shares of its common stock at $98.01$109.01 per share, 678and 82 shares of its common stock at $92.70 per share, 584 shares of its common stock at $94.69 per share, 118 shares of its common stock at $95 per share, and 10 shares of its common stock at $95.25$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 20212022 filings with the NRC were made reporting on decommissioning funding for all of Entergy subsidiaries’ nuclear plants.Palisades and the Big Rock Point dry fuel storage facility. Those reports showed that decommissioning funding for each of the nuclear plantsthose facilities met the NRC’s financial assurance requirements.
NRC Reactor Oversight Process
In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence206
Environmental Regulation
Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.
Clean Air Act and Subsequent Amendments
See the Form 10-K for discussion of the Clean Air Act and Subsequent Amendments set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.
New Source Review
As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims as well as other issues facing Entergy Arkansas’s fossil generation plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In March 2021 the District Court approved and entered the proposed settlement. For further information about the settlement, see “Regional Haze” discussed below.
National Ambient Air Quality Standards
See the Form 10-K for discussion of the National Ambient Air Quality Standards (NAAQS) set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.
Hazardous Air Pollutants
The EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011, which had a compliance date, with a widely granted one-year extension, of April 2016. The required controls have been installed and are operational at all affected Entergy units. In May 2020 the EPA finalized a rule that finds that it is not “appropriate and necessary” to regulate hazardous air pollutants from electric steam generating units under the provisions of section 112(n) of the Clean Air Act. This is a reversal of the EPA’s previous finding requiring such regulation. The final appropriate and necessary finding does not revise the underlying MATS rule. Several lawsuits have been filed challenging the appropriate and necessary finding. In February 2021 the D.C. Circuit granted the EPA’s motion to hold the litigation in abeyance pending the agency’s review of the appropriate and necessary rule. 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 must file status reports withis seeking additional information, which it could use to further tighten the court every 120 days.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 September 2016April 2022 the EPA finalized the CSAPR Update Rulepublished a rule to address interstate transport for the 20082015 ozone NAAQS. In September 2019NAAQS and which will increase the D.C. Circuit upheldstringency of the EPA’s underlying approach toCSAPR program in all four of the Update Rule, but determined that it was inconsistent withstates where the Clean Air Act because it failed to include deadlines consistent with the downward states’ deadlines for attainment. The court remandedUtility operating companies operate. If finalized as proposed, the rule towill 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 further consideration, but did not vacate it so the rule remains in effect pending the EPA’s further review. In April 2021, addressing the D.C. Circuit’s remand,selective catalytic reduction retrofits. If all of these units were retrofitted as proposed, the EPA finalized revisionsestimates that the capital cost is expected to the Update Rule, which became effective June 29, 2021. The rule finalizes interstate transport obligations for 21 states. For 12 states, including Louisiana,be approximately $1.6 billion. Additionally the EPA further reduced the number ofis proposing controls on certain non-electric generating NOx emissionsources. Since releasing the proposed rule, the price for Group 3 allowances allocatedhas 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 each state.other issues, that the EPA’s proposal represents over-control of the Entergy is currently analyzingunits in Arkansas and Mississippi; the potential impact on its facilities in Louisiana. PreliminaryEPA 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 indicates that ozone season NOx allowances may become more expensive in Louisiana, which could impactsupporting the cost of dispatching Entergy’s generating units located in Louisiana.rule.
Regional Haze
As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims and reducing the risk that Entergy Arkansas, as operator of Independence and White Bluff, might be compelled under the Clean Air Act’s regional haze program to install costly emissions control technologies. Consistent with the terms of the settlement and in many cases also the Part II state implementation plan (SIP), Entergy Arkansas, along with co-owners, agreed to begin using only low-sulfur coal at Independence and White Bluff by mid-2021; agreed to cease using coal at White Bluff and Independence by the end of 2028 and 2030, respectively; agreed to cease operation of the remaining gas unit at Lake Catherine by the end of 2027; reserved the option to develop new generating sources at each plant site; and committed to installing or proposing to regulators at least 800 MWs of renewable generation by the end of 2027, with at least half installed or proposed by the end of 2022 (which includes two existing Entergy Arkansas projects) and with all qualifying co-owner projects counting toward satisfaction of the obligation. Under the settlement, the Sierra Club and the National Parks Conservation Association also waived certain potential existing claims under federal and state environmental law with respect to specified generating plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In November 2020 the court denied motions by the Arkansas Attorney General and the Arkansas Affordable Energy Coalition to intervene and to stay the proceedings. The proposed intervenors did not appeal the ruling. The District Court approved and entered the proposed settlement in March 2021. Entergy met the settlement deadline to use low-sulfur coal, is on target to meet the other requirements of the settlement, and is in compliance with other SIP requirements.
The second planning period (2018-2028) for the regional haze program requiresrequired states to examine sources for impacts on visibility and to prepare SIPsState Implementation Plans (SIPs) by July 31, 2021. Entergy has received information collection requests from2021 which the Arkansas Department of Energy and Louisiana requesting an evaluation of technical and economic feasibility of various NOx and SO2 control technologies for Independence, Nelson 6, and Ninemile. Responses to the information requests have been submitted to the respective state agencies. Louisiana has issued its draft SIP which does not propose any additional air emissions controls for Entergy units in Louisiana. However, some public commenters believe additional air controls are cost-effective. It is not yet clear how the Louisiana DepartmentEnvironment, Division of Environmental Quality (LDEQ) will respond(ADEQ) did not meet. The ADEQ released a draft proposed SIP in its finalFebruary 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 agency, like many other state agencies, did not meetEPA for review by the July 31, 2021 deadline to submit aend of 2022.
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 LDEQ is nowMississippi Department of Environmental Quality continues to develop its SIP, but there are no Entergy sources that are expected to finalize its Regional Haze SIP in late 2021 or early 2022.be impacted.
New and Existing Source Performance Standards for 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 the Affordable Clean Energy Rule (ACE).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, the Clean Power Plan will not take effect during the rulemaking process and there currently is no regulation in place with respect to greenhouse gas emissions from existing electric generating units and states are not expected to take further action to develop and submit plans at this time. 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.
Coal Combustion ResidualsFederal Jurisdiction of Waters of the United States
As discussedIn 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.
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 in late 2017, Entergy determined that certain in-ground wastewater treatment system recycle ponds at its White Bluff and Independence facilities require management under the new EPA regulations. Each site has commenced closure of its two recycle ponds (four ponds total), priorrelating to the April 11, 2021 deadline underEntergy Louisiana (electric) rate base amount of $13.6 billion: (b) Based on December 31, 2020 test year and includes approximately $800 million for the finalized CCR ruleLake Charles Power Station and excludes $300 million for unlined recycle ponds.
Other Environmental Matters
Entergy Texas
As discussedthe Washington Parish Energy Center, included in the Form 10-K, due to COVID-19 pandemic delays,capacity rider, $100 million of transmission plant investment, included in the Texas Commission on Environmental Quality (TCEQ) extendedtransmission rider, and $300 million of distribution investment, included in the Affected Property Assessment Report (APAR) and Ecological Risk Assessment submittal dates to December 2020, which Entergy timely met. Following the TCEQ’s review of the APAR and Ecological Risk Assessment, the TCEQ issued a No Further Action determination for the site in March 2021.distribution rider.
Item 6. Exhibits
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| 3(a)4(a) - | Restated CertificateTerm Loan Credit Agreement, dated as of IncorporationMay 6, 2022, among System Energy Resources, Inc., as Borrower, the Lenders party thereto, and Royal Bank of Entergy Corporation, dated May 10, 2021 (3.1(i)Canada, as Administrative Agent (4(a) to Form 8-K filed May 10, 20216, 2022 in 1-11299)1-09067). |
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| 4(a)4(b) - | |
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| *4(c) - | First Extension and Amendment Agreement, dated as of June 3, 2022, amending the Third Amended and Restated Credit Agreement, dated as of June 3, 2021, among Entergy Corporation, as Borrower, the banksLenders and other financial institutions listed on the signature pages thereof, as Lenders,LC Issuing Banks parties thereto and Citibank, N.A., as Administrative Agent, as set forth in Exhibit A to the First Extension and LC Issuing Bank, MUFG Bank, Ltd., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto (4.1 to Form 8-K filed June 3, 2021 in 1-11299).Amendment Agreement. |
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| 4(b)*4(d) - | First Extension and Amendment Agreement, dated as of June 3, 2022, amending the Third Amended and Restated Credit Agreement, dated as of June 3, 2021, among Entergy Arkansas, LLC, as Borrower, the banksLenders and other financial institutions listed on the signature pages thereof, as Lenders,LC Issuing Banks parties thereto and Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as LC Issuing Bank,set forth in Exhibit A to the First Extension and the other LC Issuing Banks from time to time parties thereto (4.2 to Form 8-K filed June 3, 2021 in 1-10764).Amendment Agreement. |
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| 4(c)*4(e) - | First Extension and Amendment Agreement, dated as of June 3, 2022, amending the Third Amended and Restated Credit Agreement, dated as of June 3, 2021, among Entergy Louisiana, LLC, as Borrower, the banksLenders and other financial institutions listed on the signature pages thereof, as Lenders,LC Issuing Banks parties thereto and Citibank, N.A., as Administrative Agent, Wells Fargo Bank, National Associationas set forth in Exhibit A to the First Extension and BNP Paribas, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto (4.3 to Form 8-K filed June 3, 2021 in 1-32718).Amendment Agreement. |
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| 4(d)*4(f) - | First Extension and Amendment Agreement, dated as of June 3, 2022, amending the Third Amended and Restated Credit Agreement, dated as of June 3, 2021, among Entergy Texas, Inc., as Borrower, the banksLenders and other financial institutions listed on the signature pages thereof, as Lenders,LC Issuing Banks parties thereto and Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., BNP Paribas, Mizuho Bank, Ltd.as set forth in Exhibit A to the First Extension and The Bank of Nova Scotia, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto (4.4 to Form 8-K filed June 3, 2021 in 1-34360). |
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| 4(e) - | Third Amended and Restated Credit Agreement dated as of June 22, 2021, among Entergy New Orleans, LLC, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Bank of America, N.A., as Administrative Agent and LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto (4 to Form 8-K filed June 22, 2021 in 1-35747). |
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| 4(f) - | |
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| 4(g) - | |
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| 4(h) - | Term Loan Credit Agreement, dated as of June 1, 2021, between29, 2022, among Entergy Mississippi, LLC, as Borrower, the Mississippi Business Finance CorporationLenders party thereto, and System Energy Resources, Inc. relating to the Revenue Refunding Bonds (System Energy Resources, Inc. Project) Series 2021 (4(d)The Bank of Nova Scotia, as Administrative Agent (Exhibit 4.1 to Form 8-K filed June 15, 2021July 5, 2022 in 1-09067)1-31508). |
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| 10(a) - | |
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| 10(b) - | Thirty-ninthFortieth Assignment of Availability Agreement, Consent and Agreement, dated as of June 15, 2021,May 6, 2022, among System Energy Resources, Inc., Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, The Bank of New York Mellon, as Mortgage Trustee, and TheRoyal Bank of New York Mellon,Canada, as Indenture Trustee (4(b)Administrative Agent (4(c) to Form 8-K filed June 15, 2001May 6, 2022 in 1-09067). |
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| *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. |
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| *101 SCH - | Inline XBRL Schema Document. |
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| *101 PRE - | Inline XBRL Presentation Linkbase Document. |
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| *101 LAB - | Inline XBRL Label Linkbase Document. |
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| *101 CAL - | Inline XBRL Calculation Linkbase Document. |
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| *101 DEF - | Inline XBRL Definition Linkbase Document. |
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| *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.
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| * | 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.
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ENTERGY CORPORATION
ENTERGY ARKANSAS, LLC
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, LLC
ENTERGY NEW ORLEANS, LLC
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC. |
|
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| /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 6, 20214, 2022