UNITED STATES
 SECURITIES AND EXCHANGE COMMISSION
 Washington, D.C. 20549
 FORM 10-K

 (Mark One)

 ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 For the fiscal year ended

 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 For the transition period from to

 Commission
 File Number

 Exact Name of Registrant
 as specified in its charter

 State or Other Jurisdiction of
 Incorporation or Organization

 IRS Employer
 Identification Number

 1-9936
 California
 95-4137452

 1-2313
 SOUTHERN CALIFORNIA EDISON COMPANY
 California
 95-1240335

 SOUTHERN CALIFORNIA EDISON COMPANY

 2244 Walnut Grove Avenue
 2244 Walnut Grove Avenue

 (P.O. Box 976)
 (P.O. Box 800)

 Rosemead, CA 91770

 Rosemead, CA 91770

 (Address of principal executive offices)
 (Address of principal executive offices)

 (626) 302-2222

 (626) 302-1212

 (Registrant's telephone number, including area code)
 (Registrant's telephone number, including area code)

 Securities registered pursuant to Section 12(b) of the Act:

 Title of each class
 Trading Symbol(s)
 Name of each exchange on which registered

 Common Stock, no par value
 EIX
 NYSE
 LLC

 Southern California Edison Company: None

 Securities registered pursuant to Section 12(g) of the Act: None

 Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

 Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.

 Indicate by check mark whether the registrant (1) has 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 registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

 Indicate by check mark whether the registrant has 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 registrant was required to submit such files).

 Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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-12 of the Exchange Act. (Check One):

 Large Accelerated Filer
 Accelerated Filer
 Non-accelerated Filer
 Smaller Reporting Company
 Emerging growth company

 Large Accelerated Filer
 Accelerated Filer
 Non-accelerated Filer
 Smaller Reporting Company
 Emerging growth company

 If an emerging growth company, indicate by check mark if the registrant has 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 registrant has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C 7262(b)) by the registered public accounting firm that prepared or issued its audit report.

 If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.

 Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant's executive officers during the relevant recovery period pursuant to §240.10D-1(b).

 Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

 Aggregate market value of voting and non-voting common equity held by non-affiliates of the registrants as of June 28, 2024, the last business day of the most recently completed second fiscal quarter:

 Approximately $ 27.7 billion

 Wholly owned by Edison International

 Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date:

 Common Stock outstanding as of February 20, 2025:

 385,023,526
 shares

 434,888,104
 shares (wholly owned by Edison International)

 OMISSION OF CERTAIN INFORMATION

 Southern California Edison Company meets the conditions set forth in General Instruction I(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format allowed under the General Instruction.

 DOCUMENTS INCORPORATED BY REFERENCE

 Designated portions of the Edison International Proxy Statement relating to Edison International's 2025 Annual Meeting of Shareholders are incorporated by reference into Part III of this report.

 SEC Form 10-K

 Reference Number

 GLOSSARY

 v

 FORWARD-LOOKING STATEMENTS

 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 Part II, Item 7

 MANAGEMENT OVERVIEW

 Highlights of Operating Results

 Electricity Industry Trends

 2025 General Rate Case

 Cost of Capital

 Capital Program

 Southern California Wildfires and Mudslides

 RESULTS OF OPERATIONS

 Years ended December 31, 2024, 2023 and 2022

 2024 vs 2023

 2023 vs 2022

 Loss from Operations

 LIQUIDITY AND CAPITAL RESOURCES

 Available Liquidity

 Regulatory Proceedings

 Capital Investment Plan

 Decommissioning of San Onofre

 Margin and Collateral Deposits

 Edison International Income Taxes

 Historical Cash Flows

 Contractual Obligations and Contingencies

 Contractual Obligations

 Contingencies

 Off-Balance Sheet Arrangements

 MARKET RISK EXPOSURES

 Interest Rate Risk

 Commodity Price Risk

 Investment Price Risk

 Credit Risk

 CRITICAL ACCOUNTING ESTIMATES AND POLICIES

 Accounting for Contingencies

 Rate Regulated Enterprises

 i

 Nuclear Decommissioning – Asset Retirement Obligation

 Pensions and Postretirement Benefits Other than Pensions

 Contributions to the Wildfire Insurance Fund

 NEW ACCOUNTING GUIDANCE

 RISK FACTORS

 Part I, Item 1A

 RISKS RELATING TO EDISON INTERNATIONAL

 RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY

 Regulatory and Legislative Risks

 Operating Risks

 Financing Risks

 Competitive and Market Risks

 RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY

 Cybersecurity and Physical Security Risks

 Global and Regional Risks

 QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 Part II, Item 7A

 FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

 Part II, Item 8

 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM (PCAOB ID 238)

 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM (PCAOB ID 238)

 CONSOLIDATED FINANCIAL STATEMENTS

 Consolidated Statements of Income for Edison International

 Consolidated Statements of Comprehensive Income for Edison International

 Consolidated Balance Sheets for Edison International

 Consolidated Statements of Cash Flows for Edison International

 Consolidated Statements of Changes in Equity for Edison International

 Consolidated Statements of Income for Southern California Edison Company

 Consolidated Statements of Comprehensive Income for Southern California Edison Company

 Consolidated Balance Sheets for Southern California Edison Company

 Consolidated Statements of Cash Flows for Southern California Edison Company

 Consolidated Statements of Changes in Equity for Southern California Edison Company

 NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 Note 1. Summary of Significant Accounting Policies

 Note 2. Property, Plant and Equipment

 Note 3. Variable Interest Entities

 Note 4. Fair Value Measurements

 Note 5. Debt and Credit Agreements

 Note 6. Derivative Instruments

 Note 7. Revenue

 Note 8. Income Taxes

 Note 9. Compensation and Benefit Plans

 Note 10. Investments

 ii

 Note 11. Regulatory Assets and Liabilities

 Note 12. Commitments and Contingencies

 Note 13. Leases

 Note 14. Equit y

 Note 15. Accumulated Other Comprehensive Loss

 Note 16. Other Income, Net

 Note 17. Supplemental Cash Flows Information

 Note 18. Related-Party Transactions

 CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

 Part II, Item 9

 CONTROLS AND PROCEDURES

 Part II, Item 9A

 BUSINESS

 Part I, Item 1

 CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION

 Subsidiaries of Edison International

 Regulation of Edison International as a Holding Company

 Human Capital

 Insurance

 SOUTHERN CALIFORNIA EDISON COMPANY

 Regulation

 Overview of Ratemaking Process

 Purchased Power and Fuel Supply

 Competition

 Properties

 Seasonality

 SOUTHERN CALIFORNIA WILDFIRES

 Recovery of Wildfire-Related Costs

 Safety Certification and Wildfire Mitigation Plan

 Public Safety Power Shutoffs

 ENVIRONMENTAL CONSIDERATIONS

 Greenhouse Gas Regulation

 Environmental Risks

 UNRESOLVED STAFF COMMENTS

 Part I, Item 1B

 CYBERSECURITY

 Part I, Item 1C

 PROPERTIES

 Part I, Item 2

 LEGAL PROCEEDINGS

 Part I, Item 3

 Environmental Proceedings

 MINE SAFETY DISCLOSURES

 Part I, Item 4

 CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL

 INFORMATION ABOUT OUR EXECUTIVE OFFICERS

 DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

 Part III, Item 10

 EXECUTIVE COMPENSATION

 Part III, Item 11

 SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

 Part III, Item 12

 CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

 Part III, Item 13

 iii

 PRINCIPAL ACCOUNTANT FEES AND SERVICES

 Part III, Item 14

 MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

 Part II, Item 5

 Purchases of Equity Securities by Edison International and Affiliated Purchasers

 Comparison of Five-Year Cumulative Total Return

 OTHER INFORMATION

 Part II, Item 9B
 Part II, Item 6

 Insider Trading Arrangements

 FORM 10-K SUMMARY

 Part IV, Item 16

 DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS

 Part II, Item 9C

 EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

 Part IV, Item 15

 EXHIBIT INDEX

 SCHEDULES SUPPLEMENTING FINANCIAL STATEMENTS

 SIGNATURES

 This combined Form 10-K is separately filed by Edison International and SCE. Information contained in this document relating to SCE is filed by Edison International and separately by SCE. SCE makes no representation as to information relating to Edison International or its subsidiaries, except as it may relate to SCE and its subsidiaries.
 iv

 GLOSSARY
 The following terms and abbreviations appearing in the text of this report have the meanings indicated below.

 the Thomas Fire, the Koenigstein Fire, the Montecito Mudslides and the Woolsey Fire, collectively

 AB 1054
 California Assembly Bill 1054, executed by the governor of California on July 12, 2019

 AB 1054 Excluded Capital Expenditures
 $1.6 billion in wildfire risk mitigation capital expenditures that SCE has excluded from the equity portion of SCE's rate base as required under AB 1054

 AB 1054 Liability Cap
 a cap on the aggregate requirement to reimburse the Wildfire Insurance Fund over a trailing three calendar year period which applies if certain conditions are met and is equal to 20% of the equity portion of the utility's transmission and distribution rate base, excluding general plant and intangibles, in the year of the applicable prudency determination

 ARO(s)
 asset retirement obligation(s)

 CAISO
 California Independent System Operator

 Cal Advocates

 the California Public Advocates Office

 CAL FIRE

 the California Department of Forestry and Fire Protection

 CAL OES

 the California Governor's Office of Emergency Services

 Capistrano Wind
 a group of wind projects referred to as Capistrano Wind

 Capital Structure Compliance Period
 January 1, 2023 to December 31, 2025, the current compliance period for SCE's CPUC authorized capital structure

 CCAs
 community choice aggregators which are cities, counties, and certain other public agencies with the authority to generate and/or purchase electricity for their local residents and businesses

 CPUC
 California Public Utilities Commission

 CSRP
 Customer Service Re-platform, a customer service system implemented in April 2021

 DART
 a Days Away Restricted or Transferred incident, which is a work-related Occupational Safety and Health Administration recordable injury or illness that results in days away from work, restricted duty or transfer of duties

 DERs
 distributed energy resources

 DGC
 the decommissioning general contractor engaged by SCE to undertake a significant scope of decommissioning activities at San Onofre

 Eaton Fire

 a wind-driven fire that originated in Los Angeles County in January 2025

 ECS
 SCE commercial telecommunications services operated under the name of Edison Carrier Solutions

 Edison International Proxy Statement
 Proxy Statement to be filed with the SEC in connection with Edison International's Annual Meeting of Shareholders to be held on April 24, 2025

 EEI Serious Injury
 a work-related injury that is categorized as a "serious injury" by Edison Electric Institute

 EEI SIF
 a work-related fatality or an EEI Serious Injury

 EIS
 Edison Insurance Services, Inc., a wholly-owned subsidiary of Edison International licensed to provide insurance to Edison International and its subsidiaries

 Electric Service Provider
 an entity other than an investor-owned utility or CCA that provides electric power and ancillary services to retail customers

 ERRA
 Energy Resource Recovery Account

 Fast curve settings
 protective settings, used to mitigate the risk of wildfires in high fire risk areas, that enable SCE to more quickly shut off power when an electrical fault occurs than under traditional settings

 FERC
 Federal Energy Regulatory Commission

 Fitch
 Fitch Ratings, Inc.

 GAAP
 generally accepted accounting principles in the United States

 GHG
 greenhouse gas

 GRC
 general rate case

 v

 IRA
 Inflation Reduction Act of 2022

 Koenigstein Fire
 a wind-driven fire that originated near Koenigstein Road in the City of Santa Paula in Ventura County, California, on December 4, 2017

 LAFD

 the Los Angeles Fire Department

 MD&A
 Management's Discussion and Analysis of Financial Condition and Results of Operations in this report

 Montecito Mudslides
 the debris flows and flooding in Montecito, Santa Barbara County, California, that occurred in January 2018

 Moody's
 Moody's Investors Service, Inc.

 MW
 Megawatt(s)

 NDCTP
 Nuclear Decommissioning Cost Triennial Proceeding, a CPUC proceeding to review decommissioning costs

 NEM
 net energy metering

 NERC
 North American Electric Reliability Corporation

 NRC
 United States Nuclear Regulatory Commission

 OEIS
 Office of Energy Infrastructure Safety of the California Natural Resources Agency

 Collectively, all the wildfires that originated in Southern California in and after 2017 but before 2025 where SCE's equipment has been or may be alleged to be associated with the fire's ignition, except for the Thomas Fire, the Koenigstein Fire and the Woolsey Fire

 PABA
 Portfolio Allocation Balancing Account

 Palo Verde
 nuclear electric generating facility located near Phoenix, Arizona in which SCE holds a 15.8% ownership interest

 PBOP(s)
 postretirement benefits other than pension(s)

 PG&E
 Pacific Gas & Electric Company

 PSPS
 Public Safety Power Shutoff(s)

 ROE
 return on common equity

 RPS
 California's Renewables Portfolio Standard

 S&P
 Standard & Poor's Financial Services LLC

 Safety Tier 1 Contractors
 individuals assigned to contracted work activities that may be high risk and, without implementation of appropriate safety measures, may be potentially hazardous or life threatening

 San Onofre
 retired nuclear generating facility located in south San Clemente, California in which SCE holds a 78.21% ownership interest

 SCE
 Southern California Edison Company, a wholly-owned subsidiary of Edison International

 SDG&E
 San Diego Gas & Electric Company

 SEC
 U.S. Securities and Exchange Commission

 SED
 Safety and Enforcement Division of the CPUC

 SED Agreement
 an agreement dated October 21, 2021 between SCE and the SED regarding the 2017/2018 Wildfire/Mudslide Events and three other 2017 wildfires

 SoCalGas
 Southern California Gas Company

 Thomas Fire
 a wind-driven fire that originated in the Anlauf Canyon area of Ventura County, California, on December 4, 2017

 TKM
 collectively, the Thomas Fire, the Koenigstein Fire and the Montecito Mudslides

 TKM Settlement Agreement
 a settlement agreement entered into between SCE and the California Public Advocates Office in August 2024 in the CPUC-jurisdictional rate recovery proceeding related to TKM

 Track 4
 Track 4 of the 2021 GRC, which addressed SCE's revenue requirement for 2024

 Trio

 Edison Energy, LLC, an indirect wholly-owned non-utility subsidiary of Edison International doing business as "Trio"

 Turnover Rate
 the number of employees (other than interns) who leave Edison International Parent or SCE for voluntary or involuntary reasons, divided by the average number of employees during the relevant period

 vi

 WCCP
 Wildfire Covered Conductor Program

 WMP
 a wildfire mitigation plan required to be filed under AB 1054 to describe a utility's plans to construct, operate, and maintain electrical lines and equipment that will help minimize the risk of catastrophic wildfires caused by such electrical lines and equipment

 Wildfire Insurance Fund
 the insurance fund established under AB 1054

 Woolsey Fire
 a wind-driven fire that originated in Ventura County in November 2018

 vii

 FORWARD-LOOKING STATEMENTS
 This Annual Report on Form 10-K contains "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements reflect Edison International's and SCE's current expectations and projections about future events based on Edison International's and SCE's knowledge of present facts and circumstances and assumptions about future events and include any statements that do not directly relate to a historical or current fact. Other information distributed by Edison International and SCE that is incorporated in this report, or that refers to or incorporates this report, may also contain forward-looking statements. In this report and elsewhere, the words "expects," "believes," "anticipates," "estimates," "projects," "intends," "plans," "probable," "may," "will," "could," "would," "should," "targets," and variations of such words and similar expressions, or discussions of strategy or plans, are intended to identify forward-looking statements. Such statements necessarily involve risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of the risks, uncertainties and other important factors that could cause results to differ from those currently expected, or that otherwise could impact Edison International and SCE, include, but are not limited to the:
 • ability of SCE to recover its costs through regulated rates, timely or at all, including uninsured wildfire-related and debris flow-related costs (including amounts paid for self-insured retention and co-insurance), and costs incurred to mitigate the risk of utility equipment causing future wildfires;
 • the cybersecurity of Edison International's and SCE's critical information technology systems for grid control and business, employee and customer data, and the physical security of Edison International's and SCE's critical assets and personnel;
 • risks associated with the operation and maintenance of electrical facilities, including worker, contractor, and public safety issues, the risk of utility assets causing or contributing to wildfires, failure, availability, efficiency, and output of equipment and facilities, and availability and cost of spare parts;
 • impact of affordability of customer rates on SCE's ability to execute its strategy, including the impact of affordability on SCE's ability to obtain regulatory approval of, or cost recovery for, operations and maintenance expenses, proposed capital investment projects, and increased costs due to supply chain constraints, tariffs, inflation and rising interest rates;
 • ability of SCE to update its grid infrastructure to maintain system integrity and reliability, and meet electrification needs;
 • ability of SCE to implement its operational and strategic plans, including its WMP and capital investment program, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, contractor performance, changes in the CAISO's transmission plans, and governmental approvals;
 • risks of regulatory or legislative restrictions that would limit SCE's ability to implement operational measures to mitigate wildfire risk, including PSPS and fast curve settings, when conditions warrant or would otherwise limit SCE's operational practices relative to wildfire risk mitigation;
 • ability of SCE to obtain safety certifications from OEIS;
 • risk that AB 1054 does not effectively mitigate the significant exposure faced by California investor-owned utilities related to liability for damages arising from catastrophic wildfires where utility facilities are alleged to be a substantial cause, including the longevity of the Wildfire Insurance Fund and the CPUC's interpretation of and actions under AB 1054, including its interpretation of the prudency standard clarified by AB 1054;
 • ability of Edison International and SCE to effectively attract, manage, develop and retain a skilled workforce, including its contract workers;
 • decisions and other actions by the CPUC, the FERC, the NRC and other governmental authorities, including decisions and actions related to nationwide or statewide crisis, approval of regulatory proceeding settlements, determinations of authorized rates of return or return on equity, the recoverability of wildfire-related and debris flow-related costs, issuance of SCE's wildfire safety certification, wildfire mitigation efforts, approval and implementation of electrification programs, and delays in executive, regulatory and legislative actions;

 • governmental, statutory, regulatory, or administrative changes or initiatives affecting the electricity industry, including the market structure rules applicable to each market adopted by the NERC, CAISO, Western Electricity Coordinating Council, and similar regulatory bodies in adjoining regions, and changes in the United States' and California's environmental priorities that lessen the importance placed on GHG reduction and other climate related priorities;
 • potential for penalties or disallowances for non-compliance with applicable laws and regulations, including fines, penalties and disallowances related to wildfires where SCE's equipment is alleged to be associated with ignition;
 • extreme weather-related incidents (including events caused, or exacerbated, by climate change), such as wildfires, debris flows, flooding, droughts, high wind events and extreme heat events and other natural disasters (such as earthquakes), which could cause, among other things, worker and public safety issues, property damage, outages and other operational issues (such as issues due to damaged infrastructure), PSPS activations and unanticipated costs;
 • risks associated with the decommissioning of San Onofre, including those related to worker and public safety, public opposition, permitting, governmental approvals, on-site storage of spent nuclear fuel and other radioactive material, delays, contractual disputes, and cost overruns;
 • risks associated with cost allocation resulting in higher rates for utility bundled service customers because of possible customer bypass or departure for other electricity providers such as CCAs and Electric Service Providers;
 • actions by credit rating agencies to downgrade Edison International or SCE's credit ratings or to place those ratings on negative watch or negative outlook;
 • changes in tax laws and regulations, at both the state and federal levels, or changes in the application of those laws, that could affect recorded deferred tax assets and liabilities, effective tax rates and cash flows;
 • changes in rates of inflation (including whether inflation-related adjustments to SCE's authorized revenues allowed by the public utility regulators are commensurate with inflation rates), and changes in interest rates and potential future adjustments to SCE's ROE based on changes in Moody's utility bond rate index;
 • availability and creditworthiness of counterparties and the resulting effects on liquidity in the power and fuel markets and/or the ability of counterparties to pay amounts owed in excess of collateral provided in support of their obligations; and
 • cost of fuel for generating facilities and related transportation, which could be impacted by, among other things, disruption of natural gas storage facilities, to the extent not recovered, timely or at all, through regulated rate cost escalation provisions or balancing accounts.
 Additional information about risks and uncertainties, including more detail about the factors described in this report, is contained throughout this report. Readers are urged to read this entire report, including information incorporated by reference, and carefully consider the risks, uncertainties, and other factors that affect Edison International's and SCE's businesses. Forward-looking statements speak only as of the date they are made and neither Edison International nor SCE are obligated to publicly update or revise forward-looking statements. Readers should review future reports filed by Edison International and SCE with the SEC. Edison International and SCE post or provide direct links to (i) certain SCE and other parties' regulatory filings and documents with the CPUC and the FERC and certain agency rulings and notices in open proceedings in a section titled "SCE Regulatory Highlights," (ii) certain documents and information related to Southern California wildfires which may be of interest to investors in a section titled "Southern California Wildfires," and (iii) presentations, documents and information that may be of interest to investors in a section titled "Presentations and Updates" at www.edisoninvestor.com in order to publicly disseminate such information. The reports, presentations, documents and information contained on, or connected to, the Edison International investor website are not deemed part of, and are not incorporated by reference into, this report.
 Except when otherwise stated, references to each of Edison International or SCE mean each such company with its subsidiaries on a consolidated basis. References to "Edison International Parent and Other" mean Edison International Parent and its subsidiaries other than SCE and its subsidiaries and "Edison International Parent" mean Edison International on a stand-alone basis, not consolidated with its subsidiaries. Unless otherwise described, all the information contained in this report relates to both filers.

 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
 The discussion related to the changes in financial condition for 2023 compared to 2022 is incorporated by reference to Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in Edison International's and SCE's combined Annual Report on Form 10-K for the year ended December 31, 2023, which was filed with the SEC in February 2024.

 MANAGEMENT OVERVIEW

 Highlights of Operating Results
 Edison International is the ultimate parent holding company of SCE and Edison Energy, LLC, doing business as Trio. SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area across Southern, Central and Coastal California. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers. Trio's business activities are currently not material to report as a separate business segment.
 Edison International's earnings are prepared in accordance with GAAP. Management uses core earnings (loss) internally for financial planning and for analysis of performance. Core earnings (loss) are also used when communicating with investors and analysts regarding Edison International's earnings results to facilitate comparisons of the company's performance from period to period. Core earnings (loss) are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (loss) are defined as earnings attributable to Edison International shareholders less non-core items. Non-core items include income or loss from discontinued operations and income or loss from significant discrete items that management does not consider representative of ongoing earnings, such as write downs, asset impairments and other income and expense related to changes in law, outcomes in tax, regulatory or legal proceedings, and exit activities, including sale of certain assets and other activities that are no longer continuing.
 Beginning July 1, 2023, SCE implemented a customer-funded wildfire self-insurance program. With the commencement of this program, Edison International and SCE no longer consider claims-related losses for wildfires to be representative of ongoing earnings and treat such costs as non-core items.

 2024
 2023
 2024 vs. 2023
 Change

 2022

 Net income (loss) attributable to Edison International

 SCE
 $
 1,619
 $
 1,474
 $
 $

 (335)
 (277)
 (58)
 (235)

 1,284
 1,197

 Less: Non-core items

 SCE

 2017/2018 Wildfire/Mudslide Events claims and expenses, net of recoveries
 (493)
 (634)
 (1,248)

 Other Wildfire Events claims and expenses, net of recoveries1

 (162)
 (34)
 (128)
 —

 Wildfire Insurance Fund expense
 (146)
 (213)
 (214)

 Severance costs, net of recovery

 (50)
 —
 (50)
 —

 2021 NDCTP disallowance

 —
 (30)
 —

 Customer cancellations of certain ECS data services
 —
 (17)
 —

 Employment litigation matter, net of recoveries

 —
 (10)
 (23)

 Upstream lighting program decision
 —
 —
 —
 (81)

 Impairments
 —
 —
 —
 (64)

 Organizational realignment charge
 —
 —
 —
 (14)

 Sale of San Onofre nuclear fuel
 —
 —
 —

 Income tax benefit2

 (19)

 SCE non-core items

 (613)
 (661)
 (1,182)

 Customer revenues for EIS insurance contract, net of (claims)

 (4)
 (46)

 Income tax expense (benefit)2

 (9)
 (7)

 Edison International Parent and Other non-core items

 (3)
 (36)

 Total non-core items
 (616)
 (628)
 (1,153)

 Core earnings (loss)

 SCE
 2,232
 2,135
 2,029

 (332)
 (310)
 (22)
 (264)

 $
 1,900
 $
 1,825
 $
 $
 1,765

 1Charges of $4 million and $6 million related to claims from wildfires ignited prior to July 1, 2023 were included in core earnings in 2023 and 2022, respectively. Core earnings in periods before the third quarter of 2023 have not been recast to exclude these charges.
 2SCE and Edison International Parent and Other non-core items are tax-effected at an estimated statutory rate of approximately 28%; customer revenues (claims) for EIS insurance contract are tax-effected at the federal statutory rate of 21%.
 Edison International's 2024 earnings increased $87 million, driven by an increase in SCE's earnings of $145 million, offset by an increase in Edison International Parent and Other loss of $58 million. SCE's higher net income consisted of $97 million of higher core earnings and $48 million of lower non-core loss. Edison International Parent and Other's higher loss consisted of $22 million of higher core loss and $36 million of lower non-core earnings.
 The increase in SCE's core earnings was primarily due to higher revenue authorized in Track 4 and an increase in the authorized rate of return resulting from the cost of capital adjustment mechanism, partially offset by higher interest expense.
 The increase in Edison International Parent and Other's core loss was primarily due to higher interest expense.

 Consolidated non-core items for 2024 and 2023 for Edison International included:
 • Charges of $493 million ($355 million after-tax) recorded in 2024 and $634 million ($457 million after-tax) recorded in 2023 for 2017/2018 Wildfire/Mudslide Events claims and related legal expenses, net of expected FERC recoveries. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.
 • Charges of $162 million ($117 million after-tax) recorded in 2024 and $34 million ($25 million after-tax) recorded in 2023 for wildfire claims and related legal expenses, net of expected insurance and regulatory recoveries, related to the Other Wildfire Events. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.
 • Charges of $146 million ($105 million after-tax) recorded in 2024 and $213 million ($153 million after-tax) recorded in 2023 from the amortization of SCE's contributions to the Wildfire Insurance Fund. See "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies" for further information.
 • Severance costs of $50 million ($36 million after-tax), net of expected FERC recovery, recorded in 2024 due to current and probable reductions in workforce. See "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies" for further information.
 • A charge of $30 million ($21 million after-tax) recorded in 2023 for a disallowance related to the 2021 NDCTP. See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" for more information.
 • A charge of $17 million ($12 million after-tax) recorded in 2023 related to customer cancellations of certain ECS data services.
 • Insurance recovery of $10 million ($7 million after-tax) recorded in 2023, related to settlement of an employment litigation matter. SCE and Edison International settled the matter following an atypical jury award.
 • Expected wildfire claims of $4 million ($3 million after-tax) insured by EIS recorded in 2024 and net earnings of $42 million ($33 million after-tax) recorded in 2023, related to customer revenues for an EIS insurance contract offset by expected wildfire claims insured by EIS. See "Notes to Consolidated Financial Statements— Note 12. Commitments and Contingencies"
 See "Results of Operations" for discussion of SCE and Edison International Parent and Other results of operations.

 Electricity Industry Trends
 The electric power industry is undergoing urgent and fundamental changes to how energy infrastructure is planned and built, driven by: state government actions to reduce GHG emissions; new sources of demand, such as electric vehicles, data centers, and building electrification; and technological innovations that support clean energy adoption, such as distributed generation and energy storage. These factors, coupled with the increasing impacts of climate change, are altering the way in which electricity is generated and delivered. The impacts of climate change are apparent and accelerating. In 2024, the Earth experienced its hottest year on record. This spike in temperature is making extreme weather events commonplace. In California alone, climate-related disasters have cost the state tens of billions of dollars since 2018, with the 2025 wildfires being particularly devastating. Climate change is expected to have far-reaching effects on society, necessitating industry-wide solutions to enhance grid resilience and support a clean, reliable and affordable grid.
 California is committed to reducing its GHG emissions, improving local air quality and supporting continued economic growth. The state codified into law goals to reduce GHG emissions by 40% from 1990 levels by 2030 and 85% from the same baseline by 2045, as well as to be carbon neutral by 2045. State and local air quality plans also call for substantial improvements including reducing smog-causing nitrogen oxides 90% below 2010 levels by 2032 in the most polluted areas of the state.
 While these policy goals cannot be achieved by the electric sector alone, the electric grid is a critical enabler of the adoption of energy technologies that support California's GHG reduction objectives. California has set RPS targets which require California retail sellers of electricity to provide 60% of power from renewable resources by 2030. California also requires sellers of electricity to deliver 100% of retail sales from carbon-free sources by 2045, including interim targets of 90% by 2035 and 95% by 2040. In 2024, approximately 46% of SCE's customer deliveries came from carbon-free resources. SCE continues to make progress towards meeting its long-term RPS and carbon-free power goals and interim targets. In addition, Edison International is committed to achieving net-zero GHG emissions by 2045, in alignment with economy-wide climate actions planned by California. This commitment covers the power SCE delivers to customers and Edison International's enterprise-wide operations. To further support these goals, Edison International and SCE are investing in building a more resilient grid to reduce climate- and weather-related vulnerabilities. Since 2018, SCE has been

 adapting to climate change through system hardening to reduce wildfire risk. In its 2025 GRC, SCE proposed climate adaptation investments to address wildfire and physical risks that could occur by 2030.
 Edison International believes that California's 2045 goals can be achieved most economically through emissions reductions enabled by clean electricity to serve 100% of retail sales, electrifying approximately 90% of light-duty vehicles, 90% of medium-duty vehicles, 54% of heavy-duty vehicles, 80% of buses and 95% of buildings. Additionally, reducing emissions to near zero in the electric sector hinges on developing clean firm resources to replace natural gas. Clean firm resources, such as next-generation geothermal, small modular reactors, natural gas with carbon capture and storage, and clean hydrogen, produce constant power through any weather conditions or season with little or no greenhouse gas emissions. By 2045, electricity demand is projected to increase by at least 80% as compared to 2022 per Edison International's analysis. In SCE's service area, the increase in electricity demand is materializing sooner than expected. SCE's most recent 10-year load growth forecast has increased by 35% compared to its 2022 distribution system plan. The key drivers of this increase are commercial developments, transportation electrification, and new residential housing. California has demonstrated strong long-term support of transportation electrification as shown by the approval of SCE's Charge Ready programs and 2022 legislation banning sales of new gas vehicles by 2035. However, Edison International believes that more state policy support, along with public and private investment, is needed to enable California to reach its 2030 and 2045 GHG reduction targets. Additional policy and regulatory support is also needed to de-risk the development of clean firm resources, adjust planning processes to enable proactive grid build-out, and streamline permitting processes. The current federal administration has declared a national emergency on energy, stressing the need for a reliable, diversified, and affordable supply of energy. The integrity and expansion of energy infrastructure is an immediate and pressing priority.
 Edison International's vision is to lead the transformation of the electric power industry and the company is focused on opportunities in delivering clean energy, advancing electrification, building a modernized and more reliable grid, and enabling customers' technology choices. SCE's ongoing focus to drive operational and service excellence is intended to allow it to achieve these objectives safely while controlling costs and customer rates. SCE expects its bundled system average rate will rise at or below a 2.6% compound annual growth rate from 2024 through 2028, which is near the projected rate of local inflation. This projected rate growth incorporates the requested increases in SCE's 2025 GRC, and also assumes a full recovery of costs associated with the 2017/2018 Wildfire/Mudslide Events (See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" for further information, including TKM Settlement). Partially offsetting these increases are historical costs rolling out of rates and rising electricity consumption. SCE projects that, even as electricity bills increase over time, total energy costs for the average SCE household will be reduced by approximately 40% by 2045 due to the efficiency of electrified technologies among other drivers.
 SCE's investments in the grid, utility owned storage capacity, and contracts for substantial new clean energy resources are key enablers of reliable economy-wide electrification. See "—Capital Program," "Liquidity and Capital Resources—Capital Investment Plan," and "Business—SCE—Purchased Power and Fuel Supply—CAISO Wholesale Energy Market" for further details. SCE also continues to implement its transportation electrification programs. As of December 31, 2024, SCE had completed construction at 386 sites to support 6,520 charge ports under its suite of light-duty Charge Ready programs, and 99 sites to support the electrification of 2,251 medium and heavy-duty vehicles through its Charge Ready Transport program. Subject to regulatory approval, SCE plans to invest approximately $13 billion in infrastructure replacement between 2023 and 2028 to ensure the grid is reliable, resilient, and ready for widespread electrification. This represents approximately 30% of the capital plan for that same time period, as discussed in "—Capital Program."
 Changes in the electric power industry are impacting customers and jurisdictions outside California as well. Many other states and countries are also pursuing climate change and GHG reduction objectives, and large commercial and industrial customers are continuing to pursue cost reduction and sustainability goals. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers who may be impacted by these changes.
 To better engage in this broader transformation and provide a view of developments outside of SCE, Edison International has also made several investments in emerging companies in areas related to the technology and business model changes that are driving industry transformation and may make additional investments in the future. These investments are not financially material to Edison International.

 2025 General Rate Case
 SCE filed its 2025 GRC application with the CPUC in May 2023, for the four-year period of 2025 – 2028. In its application, SCE requested that the CPUC authorize a test year 2025 revenue requirement of approximately $10.3 billion. This represents a $1.9 billion, or 23%, increase over the approximately $8.4 billion 2024 revenue requirement adopted in Track 4, prior to adjustments for updated operations and maintenance escalation rates, the CPUC's decisions to adopt SCE's 2023 - 2025 cost of capital, and the expanded use of customer-funded self-insurance for wildfire-related claims.

 In February 2024, intervenors to the 2025 GRC proceeding, including Cal Advocates and The Utility Reform Network ("TURN"), submitted testimony in response to SCE's application. Cal Advocates and TURN recommended reductions to SCE's requests for load growth investments, infrastructure replacement, targeted undergrounding of conductors, and other areas of SCE's application.
 Cal Advocates in its testimony proposed a test year 2025 revenue requirement of approximately $9.3 billion, representing an increase of approximately 11% over the 2024 revenue requirement adopted in Track 4, before the adjustments described above. While TURN did not calculate a test year 2025 revenue requirement in connection with its proposals in its testimony, SCE estimates that TURN's proposals would result in a test year 2025 revenue requirement of approximately 12% over the 2024 revenue requirement adopted in Track 4, before the adjustments described above.
 In June 2024, following amendments and other revisions to rebuttal testimony, SCE updated its 2025 revenue requirement request to $10.5 billion, and proposed post-test year revenue requirement increases of approximately $670 million, $750 million and $730 million in 2026, 2027, and 2028, respectively. The updated 2025 revenue requirement included a $220 million increase associated with the cost of capital adjustment authorized by the CPUC in a separate proceeding, which was subsequently modified by a CPUC decision in October 2024, as discussed in "—Cost of Capital."
 In July 2024, the CPUC issued a decision approving SCE's request in the 2025 GRC to extend the customer-funded wildfire self-insurance through the 2025 GRC period.
 In October 2024, the CPUC approved the establishment of a memorandum account to track changes in the revenue requirement between January 1, 2025, and the implementation date of the final decision. While SCE and certain parties have entered into stipulations to resolve certain contested areas in the 2025 GRC, SCE cannot predict the revenue requirement the CPUC will ultimately authorize or forecast the timing of a final decision. SCE expects to recognize revenue based on the 2024 authorized revenue requirement, adjusted to reflect the 2025 CPUC-authorized ROE as discussed in "—Cost of Capital," until a GRC decision is issued.

 Cost of Capital
 The cost of capital adjustment mechanism set by the CPUC provides for an adjustment to SCE's authorized cost of capital that, when triggered, will impact SCE's results of operations and cash flows. In 2023, the cost of capital adjustment mechanism was triggered and resulted in an increase to SCE's CPUC-authorized ROE from 10.05% to 10.75% effective January 1, 2024. The resulting increase to SCE's 2024 GRC-related revenue requirement was $201 million. The cost of capital adjustment mechanism was not triggered in 2024. In October 2024, the CPUC issued a decision modifying the cost of capital adjustment mechanism that changed the mechanism's adjustment ratio from 50% to 20%. This modification was also applied to the increase that was most recently triggered in 2023, effective on January 1, 2025. As a result, SCE's 2025 CPUC-authorized ROE was adjusted to 10.33%. The decision reduces SCE's updated 2025 GRC-related revenue requirement by approximately $117 million. For further information, see "—2025 General Rate Case." For additional information on cost of capital and the ratemaking process, see "Business—SCE—Overview of Ratemaking Process—CPUC."
 SCE expects to file its regularly scheduled cost of capital application in March 2025 for rates effective for 2026 – 2028.

 Capital Program
 Capital Expenditures
 Total capital expenditures (including accruals) were $5.7 billion in 2024 and $5.4 billion in 2023.
 In connection with the 2025 GRC, SCE forecasts capital expenditures of $26.6 billion to $31.5 billion for 2025 – 2028. In the absence of a 2025 GRC decision, SCE has developed, and is executing against, a capital expenditure plan that is expected to allow SCE to meet what is ultimately authorized in the 2025 GRC decision while minimizing the associated risk of unauthorized spending.
 The table below reflects forecast capital expenditures for 2025 – 2028 based on planned CPUC jurisdictional spending and current management expectations of FERC-jurisdictional spending. CPUC jurisdictional spending includes amounts requested in the 2025 GRC, and other approved non-GRC CPUC capital spending. The forecast CPUC jurisdictional capital spending will be dependent upon amounts approved in the 2025 GRC. Forecasted expenditures for FERC capital projects are subject to change due to factors such as timeliness of permitting, licensing, regulatory approvals, contractor bids, supply chain issues and other operational considerations.
 Based on management's judgment of potential capital spending variability informed by historical precedent of previously authorized amounts, potential permitting delays, and other operational considerations, a range case was prepared reflecting reductions to GRC capital expenditures, CPUC non-GRC capital expenditures, and FERC capital expenditures.

 The following table sets forth a summary of capital expenditures for 2024 actual spend and a forecast for 2025 – 2028 on the basis described above:

 (in billions)
 2024
 2025
 2026
 2027
 2028
 Total
 2025 – 2028

 Traditional capital expenditures

 Distribution
 $
 4.1
 $
 5.2
 $
 5.6
 $
 5.5
 $
 5.5
 $
 21.8

 Transmission
 0.3
 0.8
 0.9
 1.0
 0.7
 3.4

 Generation
 0.2
 0.2
 0.2
 0.2
 0.1
 0.7

 Subtotal
 4.6
 6.2
 6.7
 6.7
 6.3
 25.9

 Wildfire mitigation-related capital expenditures
 1.1
 1.3
 1.4
 1.5
 1.4
 5.6

 Total capital expenditures
 $
 5.7
 $
 7.5
 $
 8.1
 $
 8.2
 $
 7.7
 $
 31.5

 Total capital expenditures using range case

 *
 $
 6.6
 $
 6.8
 $
 6.8
 $
 6.4
 $
 26.6

 *Not applicable
 In addition to the amounts presented in the table above, SCE expects to make additional CPUC capital investments, the recovery of which will be subject to future regulatory approval. This includes non-GRC programs including additional spending on an enterprise resource planning ("ERP") software implementation, an advanced metering infrastructure program and other potential investments in the grid supporting restoration, reliability, resilience and readiness. SCE expects the total expenditures of these programs to be at least $3 billion, some of which will be incurred beyond 2028. In the first half of 2025, SCE intends to file an application with the CPUC for approval of the ERP implementation and expects to include approximately $1 billion of capital expenditures through 2029.
 In May 2023, the CAISO released its 2022 – 2023 Transmission Plan based on the CPUC's projections that more than 40 gigawatts of new resources need to be added in California by 2032. As the incumbent transmission owner for a portion of these transmission projects, SCE expects to construct projects requiring capital investment of at least $2.0 billion, most of which will be incurred beyond 2028. In May 2024, the CAISO released its 2023 – 2024 Transmission Plan which identified additional transmission projects expected to be constructed by SCE by 2030 with anticipated capital expenditures of approximately $80 million.
 In addition to projects awarded to incumbent transmission owners, the CAISO also identified projects eligible for competitive solicitation. In May 2024, SCE, in association with Lotus Infrastructure Global Operations, LLC, was selected as the approved project sponsor for a 30-mile overhead transmission line project connecting San Diego and Orange Counties. The project is expected to be in-service in 2032 and SCE expects to place approximately $244 million into its transmission rate base in 2032.
 Rate Base
 SCE's year-end rate base was $45.7 billion at December 31, 2024, compared to $42.7 billion at December 31, 2023.
 Reflected below is SCE's weighted average annual rate base for 2024 – 2028, encompassing GRC capital expenditures as incorporated in the requests in the 2025 GRC application, approved non-GRC projects or programs, and FERC capital expenditures.

 (in billions)
 2024
 2025
 2026
 2027
 2028

 Rate base for expected capital expenditures
 $
 42.8
 $
 49.4
 $
 53.0
 $
 56.8
 $
 60.6

 Rate base for expected capital expenditures using range case discussed above
 *
 $
 48.1
 $
 50.4
 $
 52.8
 $
 55.3

 *Not applicable

 Southern California Wildfires and Mudslides
 Unprecedented weather conditions in California due to climate change have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area, including as recently as January 2025.
 SCE continues to implement its WMP to reduce the risk of SCE equipment contributing to the ignition of wildfires. Further to the investments SCE is making as part of its WMP, SCE also uses its PSPS program to proactively de-energize power

 lines as a last resort to mitigate the risk of significant wildfires during extreme weather events. In addition, California has increased its investment in wildfire prevention and fire suppression capabilities. Yet, the potential for catastrophic wildfire activity in SCE's service area still exists.
 Eaton Fire
 In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage and service outages for SCE customers. One of the largest of these wildfires, the Eaton Fire, ignited in SCE's service area in Los Angeles County and spread under conditions of an extreme Santa Ana windstorm.
 According to preliminary information provided by CAL FIRE, the Eaton Fire burned approximately 14,000 acres; destroyed approximately 6,018 single residence structures, 3,146 other minor structures, 96 multiple residences and 158 mixed commercial/residential and nonresidential commercial structures; damaged approximately 750 residential structures, 260 other minor structures, 28 multiple residences and 35 mixed commercial/residential and nonresidential commercial structures and resulted in 17 confirmed civilian fatalities and 9 confirmed fire personnel injuries/illnesses. In addition, fire authorities have estimated suppression costs at approximately $100 million.
 The Los Angeles County Fire Department is leading the investigation into the origin and cause of the Eaton Fire, with the assistance of CAL FIRE, and has identified a preliminary area of origin of the fire. SCE has transmission facilities in the preliminary area of origin. As part of its investigation, the Los Angeles County Fire Department has requested that SCE preserve in-place its equipment in the preliminary area of origin. The SED is also conducting an investigation with respect to the Eaton Fire.
 Multiple lawsuits related to the Eaton Fire have been initiated against SCE and Edison International. SCE's ongoing internal review into the facts and circumstances of the Eaton Fire is complex and will require significant time. SCE's review includes ongoing inspections of its facilities and records and of third-party information, including analysis of concerning images and videos that suggest a possible link to SCE's transmission facilities in the preliminary area of origin. As of February 27, 2025, based on the information it has reviewed, SCE has not determined whether its equipment was associated with the ignition of the Eaton Fire.
 SCE has $1.0 billion of customer-funded self-insurance coverage available for wildfires ignited between January 1, 2025 and December 31, 2025, subject to a shareholder contribution of up to $12.5 million. If SCE incurs losses in excess of $1.0 billion for claims for third-party damages related to the Eaton Fire, SCE will be reimbursed for such losses from the Wildfire Insurance Fund, subject to approval of the fund administrator and the Wildfire Insurance Fund's claims-paying capacity, initially approximately $21 billion for all three participating utilities. PG&E is seeking reimbursement from the Wildfire Insurance Fund for losses related to the 2021 Dixie Fire and has disclosed that, as of December 31, 2024, it had recorded aggregate recoveries from the Wildfire Insurance Fund of $925 million, of which it had received $169 million. Until the fund administrator determines that the fund will be terminated, it is expected to reimburse eligible claims on a first come, first served basis, subject to the fund administrator's review.
 A utility that has received reimbursement of eligible claims from the Wildfire Insurance Fund would file an application with the CPUC for review of its costs and expenses after it has resolved all or, if authorized by the CPUC, substantially all third-party damage claims related to a wildfire, or upon earlier request of the fund administrator. A utility that held a valid safety certification at the time of the relevant wildfire, like SCE did at the time of the Eaton Fire, will be presumed to have acted prudently unless a party in the proceeding creates "serious doubt" as to the reasonableness of the utility's conduct, in which case the utility will have the burden of dispelling that doubt and proving its conduct was prudent. The prudency standard does not necessitate perfect conduct and AB 1054 requires that the CPUC find that a utility is prudent if it determines that the utility's conduct related to the relevant ignition was consistent with actions of a reasonable utility. SCE believes that the CPUC's determination regarding the reasonableness of a utility's ignition-related conduct should be based on an evaluation of the reasonableness of the utility's overall policies, systems, and practices. The CPUC has not applied the AB 1054 prudency framework to a wildfire cost-recovery proceeding.
 SCE believes that it is a reasonable operator of its electric system. Neither SCE nor any fire agency has determined the cause of the Eaton Fire, including whether SCE's transmission equipment was associated with its ignition. If it is determined that SCE's transmission equipment was associated with the ignition of the Eaton Fire, based on the information it has reviewed as of February 27, 2025, SCE believes that it would be able to make a good faith showing that its conduct with respect to its transmission facilities in the preliminary area of origin was consistent with the actions of a reasonable utility.
 The CPUC will determine the prudency of a utility's ignition-related conduct in a formal proceeding. If the CPUC finds that a utility's conduct was not prudent, it may nevertheless allow cost recovery in full or in part taking into account factors both within and beyond the utility's control that may have exacerbated the costs and expenses, including humidity, temperature and winds. A utility that held a safety certification at the time of the ignition will be required to reimburse the

 fund only for amounts disallowed by the CPUC up to the AB 1054 Liability Cap in the year that the disallowance occurs, unless the fund administrator finds that the utility's actions or inactions relative to the ignition of the fire constitute conscious or willful disregard of the rights and safety of others, in which case the utility will be required to reimburse the fund for all amounts withdrawn. The AB 1054 Liability Cap is a cap on the aggregate requirement to reimburse the Wildfire Insurance Fund over a trailing three calendar year period and is equal to 20% of the equity portion of the utility's transmission and distribution rate base, excluding general plant and intangibles, in the year of the applicable prudency determination. Utilities will be able to seek recovery of prudently incurred uninsured wildfire costs not covered by the Wildfire Insurance Fund, assessed under the prudency standard clarified under AB 1054, through electric rates.

 Multiple lawsuits and investigations related to the 2017/2018 Wildfire/Mudslide Events have been initiated against SCE and Edison International. SCE has previously entered into settlements with a number of local public entities, subrogation and individual plaintiffs in the TKM and Woolsey Fire litigations and under the SED Agreement. As of February 20, 2025, in addition to the outstanding claims of approximately 290 of the approximately 15,000 initial individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding.
 In 2024, SCE recorded estimated losses of $490 million for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events. As a result, SCE also recorded expected recoveries through FERC electric rates of $27 million against the charge, and the resulting net charge to earnings was $463 million ($333 million after-tax).
 Through December 31, 2024, SCE has recorded estimated losses of $9.9 billion, recoveries from insurance of $2.0 billion, all of which have been collected, and expected recoveries through FERC electric rates of $440 million, $376 million of which has been collected subject to refund, related to the 2017/2018 Wildfire/Mudslide Events claims. The cumulative after-tax net charges to earnings recorded through December 31, 2024, have been $5.4 billion.
 As of December 31, 2024, SCE had paid $9.5 billion under executed settlements and had $86 million to be paid under executed settlements, including $57 million to be paid under the SED Agreement, related to the 2017/2018 Wildfire/Mudslide Events. After giving effect to all payment obligations under settlements entered into through December 31, 2024, Edison International's and SCE's best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events was $340 million.
 Estimated losses for the 2017/2018 Wildfire/Mudslide Events litigation are based on a number of assumptions and are subject to change as additional information becomes available. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged. Edison International and SCE may incur a material loss in excess of amounts accrued in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events.
 CPUC-Jurisdictional Rate Recovery
 In August 2023, SCE filed an application to seek CPUC-jurisdictional rate recovery of prudently incurred losses related to the Thomas Fire, the Koenigstein Fire and the Montecito Mudslides. SCE also sought recovery of approximately $65 million in restoration costs in the proceeding. In January 2025, the CPUC approved the TKM Settlement Agreement and closed the proceeding. Parties to the proceeding may file an application for rehearing through March 10, 2025. Under the TKM Settlement Agreement, SCE is authorized to recover 60%, or approximately $1.6 billion, of approximately $2.7 billion of losses, consisting of approximately $1.3 billion of uninsured claims paid as of May 31, 2024, and $0.3 billion of associated costs, composed of legal and financing costs incurred as of May 31, 2024, and estimated ongoing financing costs. SCE is also authorized to recover 60% of claims paid and related costs incurred after May 31, 2024, other than for $125 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. SCE will record a regulatory asset for recoveries permitted under the TKM Settlement Agreement in the first quarter of 2025 and will request approval from the CPUC to finance the amounts authorized under the TKM Settlement Agreement through the issuance of securitized bonds.
 Under the TKM Settlement Agreement, SCE is also authorized to recover approximately $55 million of approximately $65 million in restoration costs incurred. Further, SCE will use shareholder funds to offset $50 million of wildfire mitigation expenses recorded in memorandum accounts between 2024 and 2028. Under the TKM Settlement Agreement, SCE is allowed to permanently exclude from SCE's CPUC regulatory capital structure any after-tax charges to equity associated with the costs disallowed or funded by shareholders in the TKM Settlement Agreement and the debt issued to finance those costs (For further details about SCE's CPUC authorized capital structure, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends"). In October 2024, SCE filed an application to seek CPUC-jurisdictional rate recovery of $5.4 billion of prudently incurred losses related to the Woolsey Fire, consisting of approximately $4.4 billion of uninsured claims paid as of August 31, 2024, and $1.0 billion of associated costs, composed of legal and financing costs incurred as of August 31, 2024, and estimated ongoing financing

 costs. SCE is also seeking recovery of approximately $84 million in restoration costs in the proceeding. SCE will not record a regulatory asset for recoveries related to the Woolsey Fire in connection with the approval of the TKM Settlement Agreement. SCE will continue to evaluate the facts and circumstances of the Woolsey Fire cost recovery proceeding in determining if and when a regulatory asset may be recorded.
 In addition to the 2017/2018 Wildfire/Mudslide Events, several other wildfires significantly impacted portions of SCE's service area prior to 2025, including the 2017 Creek Fire, the 2019 Saddle Ridge Fire, the 2020 Bobcat Fire, the 2020 Silverado Fire, the 2022 Coastal Fire and the 2022 Fairview Fire.
 In 2024, SCE recorded estimated losses of $253 million for claims related to the Other Wildfire Events. As a result, SCE also recorded expected recoveries from insurance of $96 million and expected recoveries through electric rates of $9 million against the charge, and the resulting net charge to earnings was $148 million ($106 million after-tax).
 Through December 31, 2024, SCE has recorded total estimated losses of $1.1 billion, expected recoveries from insurance and third parties of $718 million and expected recoveries through electric rates of $177 million related to the Other Wildfire Events claims. The cumulative after-tax net charges to earnings recorded through December 31, 2024, have been $175 million.
 As of December 31, 2024, SCE had paid or is obligated to pay approximately $576 million under executed settlements related to the Other Wildfire Events and Edison International's and SCE's estimated losses for remaining alleged and potential claims (established at the low end of the estimated range of reasonably possible losses) related to the Other Wildfire Events was $563 million. As of the same date, SCE had assets for expected recoveries through insurance and third parties of $434 million and through electric rates of $149 million on its consolidated balance sheets related to the Other Wildfire Events.
 Edison International and SCE may incur material losses in excess of the amounts accrued for certain of the Other Wildfire Events. Edison International and SCE expect that additional losses incurred in connection with any such fire, other than for the Creek Fire, will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such additional losses after expected recoveries from insurance and through electric rates will not be material. For information on the Creek Fire, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" in this report.
 In light of the prudency standard the CPUC is required to apply under AB 1054 to utilities holding a safety certification at the time a wildfire ignited after July 12, 2019, SCE has concluded, at this time, that both uninsured CPUC-jurisdictional and uninsured FERC-jurisdictional wildfire-related costs related to the Other Wildfire Events that ignited after July 2019 for which it has deferred as regulatory assets are probable of recovery through electric rates. SCE will continue to evaluate the probability of recovery based on available evidence, including regulatory decisions, including any CPUC decisions illustrating the interpretation and/or application of the prudency standard under AB 1054, and, for each applicable fire, evidence that could cast serious doubt as to the reasonableness of SCE's conduct relative to that fire.
 For further information on Southern California Wildfires and Mudslides, see "Risk Factors," "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Initial and annual contributions to the wildfire insurance fund established pursuant to California Assembly Bill 1054," "Business—Southern California Wildfires" and "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" in this report.

 RESULTS OF OPERATIONS

 SCE
 The table below shows SCE's consolidated statements of income for 2024, 2023 and 2022. In general, expenses SCE is authorized to pass through directly to customers (such as purchased power and fuel expenses, flow-through taxes, as well as costs incurred for various programs and activities, such as public purpose programs and vegetation management activities) and the corresponding amount of revenues collected to recover those pass-through costs do not impact net income.

 Years ended December 31, 2024, 2023 and 2022
 The following table is a summary of SCE's results of operations for the periods indicated:

 Favorable (Unfavorable)

 2024
 2023
 2022
 2024 to 2023
 2023 to 2022

 Operating revenue
 $
 17,547
 $
 16,275
 $
 17,172
 $
 1,272
 $
 (897)

 Purchased power and fuel
 5,209
 5,486
 6,375

 Operation and maintenance
 5,064
 4,071
 4,659
 (993)

 Wildfire-related claims, net of insurance recoveries
 1,305

 Wildfire Insurance Fund expense

 2,865
 2,633
 2,559
 (232)
 (74)

 Property and other taxes
 (54)
 (69)

 —

 Total operating expenses
 14,551
 13,635
 15,659
 (916)
 2,024

 Operating income
 2,996
 2,640
 1,513
 1,127

 Interest expense
 (1,575)
 (1,356)
 (1,005)
 (219)
 (351)

 Other income, net
 (4)

 Income before income taxes
 1,914
 1,781

 Income tax expense (benefit)
 (109)
 (293)

 1,794
 1,597

 Less: Preference stock dividend requirements
 (52)
 (16)

 Net income available for common stock
 $
 1,619
 $
 1,474
 $
 $
 $

 2024 vs 2023
 Operating Revenue
 Higher operating revenue of $1,272 million is primarily due to:
 • An increase in CPUC-related revenues of $617 million primarily due to higher revenue authorized in Track 4 and an increase in the authorized rate of return resulting from the cost of capital adjustment mechanism. See "Management Overview—Cost of Capital" for more information.
 • An increase in operating revenues of $51 million primarily due to recognition of previously unrecognized return on rate base related to emergency restoration related capital expenditures.
 • A net increase in revenues of $604 million related to higher expenses that are passed through to customers. The increase in pass-through revenues is primarily offset by increases in the following:
 Operation and maintenance expense of $809 million
 Depreciation and amortization expense of $111 million
 Interest expense of $66 million
 Property and other taxes of $28 million
 These pass-through increases were offset by the decreases in the following:
 Purchased power and fuel expense of $277 million
 Income tax expense of $134 million
 Purchased Power and Fuel
 A decrease in purchased power and fuel costs of $277 million, primarily due to lower purchased power and gas prices, partially offset by an increase in purchased power volume and higher losses in hedging activities (offset in "Operating Revenue" above).
 Operation and Maintenance

 An increase in operation and maintenance expense of $993 million is primarily due to:
 • A net increase in expense of $809 million related to operating expenses that are passed through to customers and offset in "Operating Revenue" above. The increase is mainly driven by:
 $462 million due to higher previously deferred wildfire mitigation, vegetation management, and emergency restoration costs authorized for recovery in 2024 than in 2023. See "Liquidity and Capital Resources—SCE—Regulatory Proceedings" for more information
 $301 million higher vegetation management expenses
 $196 million higher public purpose program expenses
 $144 million higher uncollectible accounts expense
 $116 million higher transmission access charges
 These increases are partially offset by:
 $209 million previously deferred wildfire insurance premium authorized for recovery in 2023
 $195 million lower insurance costs due to SCE's expanded use of customer-funded self-insurance since July 2023
 •$90 million higher expenses primarily related to plant maintenance
 •$62 million higher wildfire mitigation expenses
 • Severance costs of $53 million recorded in 2024 due to current and probable reductions in workforce
 •$25 million higher expenses related to IT software maintenance and capital-related expense
 • The 2023 recognition of a $30 million disallowance related to the 2021 NDCTP
 • The 2023 recognition of $17 million related to customer cancellations of certain ECS data services
 Wildfire-related Claims, Net of Insurance Recoveries
 Charges for wildfire-related claims, net of insurance recoveries, were $647 million and $665 million in 2024 and 2023, respectively, related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
 Wildfire Insurance Fund Expense
 A decrease in wildfire insurance fund amortization expense of $67 million due to the change in the estimated life of the Wildfire Insurance Fund in the beginning of 2024, which increased the amortization period of SCE's Wildfire Insurance Fund contributions assets. See "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies" for further information.
 Depreciation and Amortization
 An increase in depreciation and amortization expense of $232 million due to an increase of $121 million primarily driven by higher plant balances and $111 million of pass-through costs (offset in "Operating Revenue" above). The pass-through costs are mainly related to emergency restoration and wildfire mitigation activities.
 Property and Other Taxes
 An increase in property and other taxes of $54 million due to an increase of $26 million primarily related to higher assessed property values and $28 million of pass-through costs (offset in "Operating Revenue" above).
 Interest Expense
 An increase in interest expense of $219 million due to an increase of $153 million primarily related to higher interest rates on long-term debt and balancing account overcollections, and additional long-term borrowings, and $66 million of pass-through costs mainly related to emergency restoration activities and AB 1054 Excluded Capital Expenditures financed through securitization (offset in "Operating Revenue" above).

 Preference Stock Dividend Requirements
 An increase in preference stock dividend requirements of $52 million primarily due to additional preference stock outstanding.
 A decrease in income tax expense of $64 million, primarily due to $97 million higher flow-through tax benefits that are passed through to customers, partially offset by an increase in tax expense on pre-tax income. See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for a reconciliation of the federal statutory rate to the effective income tax rate.

 2023 vs 2022
 Operating Revenue
 An increase in operating revenue of $897 million is primarily due to:
 • A net decrease in revenues of $1,231 million related to lower expenses that are passed through to customers. The decrease in pass-through revenues are offset by decreases in the following:
 Purchased power and fuel expense of $889 million
 Operation and maintenance expense of $482 million
 Wildfire-related claims, net of insurance recoveries of $37 million
 These pass-through decreases are partially offset by increases in the following:
 Income tax expense of $43 million
 Interest expense of $39 million
 Property and other taxes of $38 million
 Other income, net, of $37 million
 Depreciation and amortization expense of $17 million
 • An increase in CPUC-related revenues of $320 million primarily due to the escalation mechanism set forth in the 2021 GRC decision.
 Purchased Power and Fuel
 A decrease in purchased power and fuel costs of $889 million, primarily lower prices and volumes for both purchased power and gas, partially offset by hedging activities (offset in "Operating Revenue" above).
 Operation and Maintenance
 A decrease in operation and maintenance expense of $588 million is primarily due to:
 • A net decrease in expense of $482 million related to the operating expenses that are passed through to customers and offset in "Operating Revenue" above. The decrease is mainly driven by:
 $463 million due to lower previously deferred wildfire mitigation and emergency restoration costs authorized for recovery in 2023 than in 2022
 $218 million lower insurance costs due to SCE's expanded use of customer-funded self-insurance since July 2023
 $79 million lower uncollectible accounts expense primarily due to the recognition of $109 million previously deferred uncollectible accounts expense in 2022
 $56 million lower transmission access charges
 The decreases are partially offset by:
 $209 million previously deferred wildfire insurance premium authorized for recovery in 2023
 $125 million higher public purpose program expenses

 • The 2022 charges of $95 million related to the CPUC's decision on SCE's Upstream Lighting Program, consisting of $76 million in disallowed costs and $19 million in fines
 •$40 million lower uncollectible accounts expense due to expense recognized in 2022 not subject to cost recovery
 • The 2023 recognition of a $30 million probable disallowance related to the 2021 NDCTP
 Wildfire-related Claims, Net of Insurance Recoveries
 Charges for wildfire-related claims, net of insurance recoveries, were $665 million and $1.3 billion in 2023 and 2022, respectively, related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events.
 Depreciation and Amortization
 An increase in depreciation and amortization expense of $74 million due to an increase of $57 million primarily driven by higher plant balances and $17 million of pass-through costs (offset in "Operating Revenue" above).
 Property and Other Taxes
 An increase in property and other taxes of $69 million due to an increase of $31 million primarily related to higher assessed property values and $38 million of pass-through costs (offset in "Operating Revenue" above).
 Impairments were recorded in 2022, of which $17 million related to disallowed capital expenditure and $47 million related to a settlement agreement between SCE and TURN in the CSRP proceeding.
 Interest Expense
 An increase in interest expense of $351 million due to an increase of $312 million primarily related to higher interest rates on long-term debt and balancing account overcollections and additional long-term borrowings, and $39 million of pass-through costs primarily related to AB 1054 Excluded Capital Expenditures financed through securitization (offset in "Operating Revenue" above).
 Other income, net
 An increase in other income, net of $160 million primarily due to higher interest rates applied to balancing account undercollections and increased equity allowance for funds used during construction, partially offset by lower net periodic benefit income related to the non-service cost components for SCE's pension and PBOP.
 Preference Stock Dividend Requirements
 An increase in preference stock dividend requirements of $16 million primarily due to dividends paid on Series E preference stock at a higher rate.
 An increase in tax expense of $293 million in 2023 compared to a tax benefit recorded in 2022, primarily due to higher taxable income and $42 million lower flow-through tax benefits that are passed through to customers.

 Results of operations for Edison International Parent and Other include amounts from other subsidiaries that are not reportable segments, as well as intercompany eliminations.

 Loss from Operations
 The following table summarizes the results of Edison International Parent and Other:

 Favorable (Unfavorable)

 2024
 2023
 2022
 2024 to 2023
 2023 to 2022

 Edison International Parent and Other net loss
 $
 (248)
 $
 (190)
 $
 (130)
 $
 (58)
 $
 (60)

 Less: Preferred stock dividend requirements
 —

 Edison International Parent and Other net loss attributable to common shareholders
 $
 (335)
 $
 (277)
 $
 (235)
 $
 (58)
 $
 (42)

 The net loss attributable to common shareholders from operations of Edison International Parent and Other increased $58 million in 2024 compared to 2023 primarily due to lack of earnings from an EIS insurance contract and higher interest expense.
 The net loss attributable to common shareholders from operations of Edison International Parent and Other increased $42 million in 2023 compared to 2022 primarily due to higher interest expense, partially offset by gains on preferred stock repurchases of $16 million.

 LIQUIDITY AND CAPITAL RESOURCES

 SCE
 SCE's ability to operate its business, fund capital expenditures, and implement its business strategy is dependent upon its operating cash flow and access to the bank and capital markets. SCE's overall cash flows fluctuate based on, among other things, its ability to recover its costs in a timely manner from its customers through regulated rates, changes in commodity prices and volumes, collateral requirements, interest obligations, dividend payments to and equity contributions from Edison International, obligations to preference shareholders, and the outcome of tax, regulatory and legal matters.
 In the next 12 months, SCE expects to fund its cash requirements through operating cash flows, and capital market and bank financings. SCE also has availability under its credit facility to fund cash requirements. SCE expects to issue additional debt for general corporate purposes, and to securitize the recovery of 2017/2018 Wildfire/Mudslide Events as permitted by the TKM Settlement Agreement subject to the filing and approval of a securitization financing order.
 SCE issued securitized bonds in the amounts of $775 million and $533 million in 2023 and 2022, respectively, to finance the required AB 1054 Excluded Capital Expenditures and related financing costs. For more information, see "Notes to Consolidated Financial Statements––Note 5. Debt and Credit Agreements."
 The following table summarizes SCE's current long-term issuer credit ratings and outlook from the major credit rating agencies, and SCE's credit rating outlook as of February 20, 2025:

 Moody's
 Fitch
 S&P

 Credit Rating
 Baa1
 BBB
 BBB

 Outlook
 Stable
 Stable
 Negative

 SCE's credit ratings may be affected if, among other things, regulators fail to successfully implement AB 1054 in a consistent and credit supportive manner, or the Wildfire Insurance Fund is materially depleted, or a persistent increase in the frequency of severe wildfires in California leads the credit rating agencies to believe the Wildfire Insurance Fund is at risk of a material depletion. Credit rating downgrades increase the cost and may impact the availability of short-term and long-term borrowings, including commercial paper, credit facilities, bond financings or other borrowings. In addition, some of SCE's power procurement contracts and environmental remediation obligations would require SCE to pay related liabilities or post additional collateral if SCE's credit rating were to fall below investment grade. For further details, see "—Margin and Collateral Deposits."
 For restrictions on SCE's ability to pay dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."

 Available Liquidity
 At December 31, 2024, SCE had cash on hand of $78 million and approximately $2.1 billion available to borrow on its $3.4 billion revolving credit facility. The credit facility is available for borrowing needs until May 2028. The aggregate maximum principal amount under the SCE revolving credit facility may be increased up to $4.0 billion, provided that additional lender commitments are obtained. SCE also had standby letters of credit with total capacity of $625 million, and the unused amount was $507 million as of December 31, 2024. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
 At December 31, 2024, SCE had $1.3 billion outstanding commercial paper, net of discount, at a weighted average interest rate of 4.95% supported by the revolving credit facility. In January 2025, SCE issued $850 million and $650 million of first and refunding mortgage bonds due in 2035 and 2055, respectively. The proceeds were used to repay commercial paper borrowings outstanding as of December 31, 2024 and for general corporate purposes.
 SCE may finance balancing account undercollections and working capital requirements to support operations and capital expenditures with commercial paper, its credit facilities or other borrowings, subject to availability in the capital markets. As necessary, SCE will utilize its available liquidity, capital market financings, other borrowings or parent company equity

 contributions in order to meet its obligations as they become due, including costs related to wildfire events. For further information, see "Management Overview—Southern California Wildfires and Mudslides."
 Debt Covenant
 SCE's credit facilities and term loan require a debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.65 to 1. At December 31, 2024, SCE's debt to total capitalization ratio was 0.58 to 1.
 At December 31, 2024, SCE was in compliance with all financial covenants that affect access to capital.

 Regulatory Proceedings
 Wildfire Related Regulatory Proceedings
 In response to the increase in wildfire activity and faster progression of and increase in damage from wildfires across SCE's service area and throughout California, SCE has incurred wildfire mitigation and wildfire and drought restoration related spending at levels significantly exceeding amounts authorized in SCE's GRCs. For regulatory proceedings related to the 2017/2018 Wildfire/Mudslide Events, see "Management Overview—Southern California Wildfires and Mudslides."
 2021 GRC Wildfire Mitigation Memorandum Account Balances
 In June 2022, SCE filed an application with the CPUC requesting reasonableness review of the incremental costs incurred in 2021 related to non-WCCP wildfire mitigation and vegetation management activities, requesting a total revenue requirement of approximately $327 million plus an ongoing capital-related revenue requirement. In March 2024, the CPUC issued a decision fully authorizing SCE's requested revenue requirement. The revenue requirement is being recovered in rates over 12 months starting June 1, 2024.
 In October 2023, SCE requested authority to recover a revenue requirement of $384 million, including interest associated with 2022 operations and maintenance and capital expenditures above levels authorized in wildfire mitigation accounts and the vegetation management balancing account. In July 2024, the CPUC approved SCE's request for interim rate recovery of $210 million of this revenue requirement, subject to refund. The revenue requirement for interim rate recovery is being recovered in rates over 17 months starting October 1, 2024. A final decision for the total authorized revenue requirement is expected in the second quarter of 2025 according to the CPUC adopted schedule.
 2020 Emergency Wildfire Restoration
 SCE filed a catastrophic event memorandum account application in 2022, primarily related to restoration efforts related to multiple 2020 wildfires. In May 2024, the CPUC issued a decision approving the recovery of SCE's capital request of $312 million and operation and maintenance expenses of $200 million, resulting in a revenue requirement of $191 million plus its ongoing capital-related revenue requirement. The revenue requirement is being recovered in rates over a 12-month period starting October 1, 2024.
 Multi-year Wildfire Mitigation and Catastrophic Events Filing ("WMCE Filing")
 In April 2024, SCE filed its WMCE Filing, seeking to recover incremental operating and maintenance expenses of $320 million and incremental capital expenditures of $702 million, primarily associated with 2019 – 2023 WCCP capital expenditures recorded in the wildfire risk mitigation balancing account, 2023 operations and maintenance and capital expenditures incremental to amounts authorized in wildfire mitigation accounts and the vegetation management balancing account, storm-related costs associated with certain 2020 – 2022 events recorded in the catastrophic event memorandum account, and certain wildfire liability insurance premium expenses recorded in the wildfire expense memorandum account, which were denied without prejudice in a previous decision. In July 2024, the CPUC adopted a schedule with a proposed decision expected in the third quarter of 2025.
 ERRA Trigger Application
 SCE recovers its fuel and purchased power-related costs through various balancing accounts, primarily the ERRA and the PABA. SCE sets rates based on an annual forecast of the costs that it expects to incur during the subsequent year. The aggregate overcollection in the ERRA and the eligible portion of the PABA at April 30, 2024 resulted in SCE triggering an established mechanism, which required SCE to file an expedited application for the CPUC's approval to reduce bundled service generation rates (see "Business—SCE—Overview of Ratemaking Process" for further information about the trigger

 mechanism). The CPUC approved this application in August 2024, resulting in a $742 million reduction in the revenue requirement, returned through rates over a 12-month period starting October 1, 2024.
 2025 FERC Formula Rate Annual Update
 In November 2024, SCE filed its 2025 annual transmission revenue requirement update with the FERC, with rates effective January 1, 2025. The update reflects a 2025 transmission revenue requirement of $1.3 billion, which is a $220 million, or 20% increase from the 2024 annual rates. The increase is primarily due to 2024 rates including a return of prior year overcollections.

 Capital Investment Plan
 Major Transmission Projects
 A summary of SCE's most significant transmission and substation construction projects is presented below. The timing of the projects below is subject to timely receipt of permitting, licensing, and regulatory approvals.

 Project Name
 Project
Lifecycle Phase
 Direct
 Expenditures
 (in millions)1

 Inception to Date
 (in millions)1

 Scheduled In-
Service Date

 Riverside Transmission Reliability2

 Licensing
 2029

 Alberhill System3

 Licensing
 2029

 Eldorado-Lugo-Mohave Upgrade
 Construction
 2025

 1Direct expenditures include direct labor, land, and contract costs incurred for the respective projects and exclude overhead costs that are included in the capital expenditures forecast discussed in "Management Overview—Capital Program."
 2Direct expenditures were adjusted for inflation with no change to the scope of the project.
 3In June 2023, SCE filed an amended application for a certificate of public convenience and necessity ("CPCN") with technical design modifications and engineering refinements to the proposed project that decreases project costs and reduces GHG emissions. Accordingly, the direct expenditures of the project are estimated to be reduced from $486 million to $472 million. SCE is unable to predict the final project costs for the Alberhill System Project.
 Riverside Transmission Reliability Project
 The Riverside Transmission Reliability Project is a joint project between SCE and Riverside Public Utilities ("RPU"), the municipal utility department of the City of Riverside. While RPU will be responsible for constructing some of the project's facilities within Riverside, SCE's portion of the project consists of constructing upgrades to its system, including a new 230 kV substation; certain interconnection and telecommunication facilities and overhead transmission lines in the cities of Riverside, Jurupa Valley and Norco and in portions of unincorporated Riverside County. In May 2022, the Riverside City Council ("RCC") voted to investigate alternatives to the CPUC approved project. Consequently, SCE suspended all major activities on the project. In January 2023, the RCC voted to establish a working group to pursue funding for additional undergrounding. In October 2023, the City of Norco filed a petition for modification ("PFM") to modify the CPUC decision approving the project and reopen the record to reconsider full undergrounding. In November 2023, SCE filed a response opposing the PFM. In March 2024, the CPUC denied the PFM. In May 2024, the RCC voted to move forward with the original scope of the project and SCE restarted its work on the project. In July 2024, SCE initiated construction bid solicitations with awards expected in the first half of 2025.
 Alberhill System Project
 The Alberhill System Project consists of constructing a new 500 kV substation, two 500 kV transmission lines to connect the proposed substation to the existing Serrano-Valley 500 kV transmission line, telecommunication equipment, and subtransmission lines in western Riverside County. The project was designed to meet long-term forecasted electrical demand in the proposed Alberhill System Project area and to increase electrical system reliability and resiliency. In April 2018 and July 2018, the CPUC issued a proposed decision and an alternate proposed decision, both denying SCE's ability to construct the Alberhill System Project based on a perceived lack of need. SCE filed comments on both proposed decisions requesting that the CPUC grant the CPCN for the Alberhill System Project. In August 2018, the CPUC issued a decision that did not deny or approve the Alberhill System Project but directed SCE to submit supplemental information on the Alberhill System Project, including, but not limited to, a load forecast and cost benefit analysis of several alternatives to the proposed project. In January 2020, SCE submitted a supplemental analysis to the CPUC for the Alberhill System Project including several alternatives to the proposed project as well as an update to the original project cost. In June 2023, SCE filed an amended CPCN with technical design modifications and engineering refinements to the proposed project that decrease project costs and reduce GHG emissions. In June 2024, the CPUC issued an addendum to its 2017 Final

 Environmental Impact Report, concluding its California Environmental Quality Act review. The project is now seeking final CPUC approval to begin construction. SCE is expecting the final CPUC decision in the second half of 2025.
 Approximately 48% of the Alberhill System Project costs spent to date would be subject to recovery through CPUC revenue and 52% through FERC revenue. In October 2017, SCE obtained approval from the FERC for abandoned plant treatment for the Alberhill System Project, which allows SCE to seek recovery of 100% of all prudently incurred costs after the approval date and 50% of prudently incurred costs prior to the approval date. As of December 31, 2024, SCE had incurred approximately $69 million of capital expenditures, which excludes land costs that may be recovered through sale to a third party and includes overhead costs, of which approximately $48 million may not be recoverable if the project is cancelled.
 Eldorado-Lugo-Mohave Upgrade Project
 The Eldorado-Lugo-Mohave Upgrade Project will increase capacity on existing transmission lines to allow additional renewable energy to flow from Nevada to southern California. The project would modify SCE's existing Eldorado, Lugo, and Mohave electrical substations to accommodate the increased power flows from Nevada to southern California; increase the power flow through the existing 500 kV transmission lines by constructing two new capacitors along the lines; raise transmission tower heights to meet ground clearance requirements; and install fiber optics on the transmission lines to provide communications between existing SCE substations. In August 2020, the CPUC approved the CPCN for the project.
 Construction for the project began in November 2020. The total costs for the Eldorado-Lugo-Mohave Upgrade Project are expected to exceed amounts currently approved in the CPCN granted by the CPUC due to delays in regulatory approvals, contractor performance issues, supply chain constraints, COVID-19 impacts, and the availability of CAISO outage windows. In May 2023, SCE filed a PFM of the decision that approved the project to increase the maximum reasonable and prudent cost for the project, which increased the direct expenditures from $247 million to $319 million. SCE expects the project to be in service in 2025, subject to the completion of environmental agency review of the mitigation work. Additional work after the in-service date is required to mitigate the impact of the project on nearby natural gas transmission lines. SCE's current estimate of the additional work is $64 million. SCE anticipates filing a second PFM or amending the existing PFM to address the additional costs of the mitigation work once the scope and cost of this work is finalized.
 Utility Owned Storage Projects
 In October 2021, SCE contracted with Ameresco, Inc. ("Ameresco") for the construction of utility owned energy storage projects at three sites in SCE's service area with an aggregate capacity of 537.5 MW, consisting of a 225 MW project, a 200 MW project, and a 112.5 MW project, and an in-service date of August 1, 2022. The 200 MW and 112.5 MW projects went in-service during the third quarter of 2024, and Ameresco has advised SCE that it currently expects the 225 MW project to be in-service by the first quarter of 2025. SCE believes that there is risk of delay beyond Ameresco's projected in-service date.
 In April 2022, SCE received a force majeure event notice from Ameresco in which Ameresco asserted that both manufacturing delays related to COVID-19 shut-downs in China and new shipping restrictions imposed by Chinese governmental authorities were then impacting the supply of batteries from China necessary for timely completion of the projects. Ameresco subsequently supplemented its force majeure notice noting additional supply chain issues related to COVID-19. Permitting delays and engineering issues and certain changes requested by SCE also impacted the projects in 2022. In January 2023, SCE received a force majeure event notice from Ameresco in which Ameresco asserted that severe winter storms in Southern California had impacted the timely completion of the projects.
 In April 2023, Ameresco discovered damage to some of the equipment at the 225 MW project. Ameresco has sent SCE a notice of potential force majeure event and has concluded that the damage was caused by soil heave and that the soil heave was caused by extreme rainstorms at the project site in the winter of 2022 – 2023. Ameresco is performing corrective action in response to the damage discovered in 2023.
 SCE is continuing to evaluate the force majeure event notices and is awaiting additional information from Ameresco on the underlying events. If there is a valid force majeure event under the contracts with Ameresco, subject to certain conditions, the project schedules and any related triggers of liquidated damages may be extended, and the contract prices may be increased to account for the impact of the force majeure event.
 SCE currently expects these storage projects to result in $1.0 billion of capital expenditures of which approximately $800 million has been incurred, as of December 31, 2024. SCE also expects to receive in aggregate approximately $380 million of tax credits available under the IRA for all three projects, which will accrue to the benefit of its customers (see "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for further information). Because Ameresco did not achieve an in-service date of August 1, 2022, SCE is entitled to liquidated damages under the terms of the contracts subject to any relief Ameresco may be entitled to under the contracts, including any relief for any valid force majeure

 events. Once triggered, delay-related liquidated damages accrue daily for up to 60 days up to a maximum of $89 million in aggregate for all three projects.
 Ameresco has obtained surety bonds to secure its obligations to complete the construction of the projects, and is also required to obtain surety bonds or letters of credit after completion of the projects to secure its performance obligations, including its warranty obligations. If Ameresco is unable to fulfill its obligations and the amounts available under any surety bonds or letters of credit are insufficient or the issuer of any such surety bonds or letters of credit disputes coverage or otherwise does not perform or pay for the performance of Ameresco's obligations, SCE will incur additional costs beyond its contractual obligations.
 In December 2021, the CPUC approved recovery of the capital expenditures and establishment of a balancing account for the associated revenue requirement, which have been reflected in rates beginning in the first quarter of 2022. Authorized revenue requirements have been and will continue to be included in the annual ERRA review proceeding and can only be disallowed upon a finding that SCE failed to prudently administer the contracts.

 Decommissioning of San Onofre
 The decommissioning of a nuclear plant requires the management of three related activities: radiological decommissioning, non-radiological decommissioning, and the management of spent nuclear fuel. SCE is the operating agent of San Onofre and has engaged the DGC to undertake a significant scope of decommissioning activities for Units 1, 2, and 3 at San Onofre. The decommissioning of San Onofre is expected to take many years. SCE funds decommissioning costs, including costs associated with storing spent nuclear fuel, with assets that are currently held in nuclear decommissioning trusts.
 Under federal law, the U.S. Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. Two Independent Spent Fuel Storage Installations ("ISFSI") store nuclear fuel onsite at San Onofre. The first stores nuclear fuel from all three Units ("ISFSI 1") and the second stores nuclear fuel from Units 2 and 3 ("ISFSI 2").
 SCE's Coastal Development Permits, the principal discretionary permits required for maintaining the ISFSIs onsite, currently extend through 2035.
 Decommissioning of San Onofre Unit 1 began in 1999 and the transfer of spent nuclear fuel from Unit 1 to dry cask storage in ISFSI 1 was completed in 2005. Major decommissioning work for Unit 1 has been completed except for certain underground work.
 Decommissioning of San Onofre Units 2 and 3 began in June 2013 and the transfer of spent nuclear fuel from San Onofre Units 2 and 3 to dry cask storage in the two ISFSIs was completed in August 2020. In August 2020, SCE commenced, and is currently conducting, major decommissioning activities in accordance with the terms of the Coastal Developmental Permit for decommissioning San Onofre Units 2 and 3.
 SCE's share of the San Onofre Units 2 and 3 decommissioning costs recorded for the years ended December 31, 2024 and 2023 were $218 million (in 2024 dollars) and $226 million (in 2023 dollars), respectively. The CPUC conducts a reasonableness review of recorded decommissioning costs in NDCTPs, which are submitted every three years.
 SCE filed the 2021 NDCTP with the CPUC in February 2022 to request reasonableness review of approximately $570 million (SCE share in 2022 dollars) of recorded San Onofre Units 2 and 3 decommissioning costs incurred during the period 2018 to 2020, and subsequently agreed to a $30 million disallowance under a settlement with the relevant intervenors. In the third quarter of 2024, the CPUC approved the 2021 NDCTP, as modified by the settlement agreement, and SCE made a contribution accordingly to the non-qualified nuclear decommissioning trust to effectuate the disallowance.
 SCE filed its 2024 NDCTP in December 2024. In the 2024 NDCTP, SCE requests reasonableness review of approximately $538 million (SCE share in 2024 dollars) of recorded San Onofre Units 2 and 3 decommissioning costs incurred during the period 2021 to 2023. SCE also requests approval of an updated decommissioning cost estimate for decommissioning activities to be completed at San Onofre Units 2 and 3 of $3.0 billion, of which $2.3 billion is SCE's share (in 2024 dollars). The decommissioning cost estimate includes costs through the expected decommissioning completion date, currently estimated to be in 2056.
 Decommissioning cost estimates are subject to a number of uncertainties including the cost and timing of nuclear waste disposal, the time it will take to obtain required permits, cost of removal of property, site remediation costs, as well as a number of other assumptions and estimates, including when the federal government will provide for either interim or permanent off-site storage of spent nuclear fuel enabling the removal and transport of spent fuel canisters from the San

 Onofre site, as to which there can be no assurance. Cost estimates are subject to change as decommissioning proceeds and such changes may be material.
 SCE had nuclear decommissioning trust funds for San Onofre Units 2 and 3 of $2.1 billion at December 31, 2024 and $2.2 billion at December 31, 2023. Based upon the resolution of a number of uncertainties, including the uncertainties of decommissioning discussed above, the financial performance of the nuclear decommissioning trust fund investments, as well as the resolution of a number of other assumptions and estimates, additional contributions to the nuclear decommissioning trust's funds may be required. If additional contributions to the nuclear decommissioning trust funds become necessary, SCE will seek recovery of additional contributions to the decommissioning trust through electric rates and any such recovery will be subject to a reasonableness review by the CPUC. Cost increases resulting from contractual disputes, delays in performance by the contractor, elevated levels of inflation, or permitting delays, among other things, could cause SCE to materially overrun the decommissioning cost estimate and could materially impact the sufficiency of trust funds.
 In December 2024, the CPUC approved disbursements from SCE's nuclear decommissioning trusts to cover forecasted 2025 decommissioning costs for San Onofre Units 2 and 3, of which SCE's share is approximately $245 million in 2025 dollars.

 Margin and Collateral Deposits
 Certain derivative instruments, power and energy procurement contracts, and other contractual arrangements contain collateral requirements. In addition, certain environmental remediation obligations require financial assurance that may be in the form of collateral postings. Future collateral requirements may differ from the requirements at December 31, 2024 due to the addition of incremental power and energy procurement contracts with collateral requirements, if any, the impact of changes in wholesale power and natural gas prices on SCE's contractual obligations, and the impact of SCE's credit ratings falling below investment grade.
 The table below provides the amount of collateral posted by SCE to its counterparties as well as the potential collateral that would have been required as of December 31, 2024, if SCE's credit rating had been downgraded to below investment grade as of that date. The table below also provides the potential collateral that could be required due to adverse changes in wholesale power and natural gas prices over the remaining lives of existing power and fuel derivative contracts.
 In addition to amounts shown in the table, power and fuel contract counterparties may also institute new collateral requirements, applicable to future transactions to allow SCE to continue trading in power and fuel contracts at the time of a downgrade or upon significant increases in market prices. Furthermore, SCE may also be required to post up to $50 million in collateral in connection with its environmental remediation obligations, within 120 days of the end of the fiscal year in which a downgrade below investment grade occurs.

 Collateral posted as of December 31, 20241

 $

 Incremental collateral requirements for purchased power and fuel contracts resulting from a potential downgrade of SCE's credit rating to below investment grade2

 Incremental collateral requirements for SCE's financial hedging activities resulting from adverse market price movement3

 Posted and potential collateral requirements
 $

 1Net collateral provided to counterparties and other brokers consisted of $128 million in letters of credit and surety bonds and $81 million of cash collateral.
 2Represents potential collateral requirements for accounts payable and mark-to-market valuation at December 31, 2024. Requirement varies throughout the period and is generally lower at the end of the month.
 3Incremental collateral requirements were based on potential changes in SCE's forward positions as of December 31, 2024 due to adverse market price movements over the remaining lives of the existing power and fuel derivative contracts using a 95% confidence level.

 In the next 12 months, Edison International Parent expects to fund its net cash requirements through cash on hand, dividends from SCE, and capital market and bank financings. Edison International Parent may finance its ongoing cash requirements, including dividends, working capital requirements, payment of obligations, and capital investments, including capital contributions to subsidiaries, with short-term or other financings, subject to availability in the bank and capital markets.

 At December 31, 2024, Edison International Parent had cash on hand of $115 million and $1.1 billion available to borrow on its $1.5 billion revolving credit facility. The credit facility is available for borrowing needs until May 2028. The aggregate maximum principal amount under the Edison International Parent revolving credit facility may be increased up to $2.0 billion, provided that additional lender commitments are obtained. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
 At December 31, 2024, Edison International Parent had $444 million outstanding commercial paper, net of discount, at a weighted-average interest rate of 4.86% supported by the revolving credit facility.
 Edison International Parent has $800 million of debt maturities arising in the next 12 months. Edison International expects to issue debt to refinance these maturities.
 On February 27, 2025, Edison International declared a dividend of $0.8275 per share to be paid on April 30, 2025. Edison International Parent and Other's liquidity and its ability to pay operating expenses and pay dividends to common shareholders are dependent on access to the bank and capital markets, dividends from SCE, realization of tax benefits and its ability to meet California law requirements for the declaration of dividends. Prior to declaring dividends, the Edison International Board of Directors evaluates available information, including when applicable, information pertaining to wildfire events, to ensure that the California law requirements for the declarations are met. For information on the California law requirements on the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." Edison International intends to maintain its target payout ratio of 45% – 55% of SCE's core earnings, subject to the factors identified above.
 Edison International's ability to declare and pay common dividends may be restricted under the terms of its Series A and Series B Preferred Stock. For further information see "Notes to Consolidated Financial Statements—Note 14. Equity."
 Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.70 to 1. At December 31, 2024, Edison International's consolidated debt to total capitalization ratio was 0.65 to 1.
 At December 31, 2024, Edison International Parent was in compliance with all financial covenants that affect access to capital.
 The following table summarizes Edison International Parent's current long-term issuer credit ratings and outlook from the major credit rating agencies, and Edison International Parent's credit rating outlook as of February 20, 2025:
 Moody's
 Fitch
 S&P

 Credit Rating
 Baa2
 BBB
 BBB

 Outlook
 Stable
 Stable
 Negative

 Edison International Parent's credit ratings may be affected if, among other things, regulators fail to successfully implement AB 1054 in a consistent and credit supportive manner, or the Wildfire Insurance Fund is materially depleted, or a persistent increase in the frequency of severe wildfires in California leads the credit rating agencies to believe the Wildfire Insurance Fund is at risk of a material depletion. Credit rating downgrades increase the cost and may impact the availability of short-term and long-term borrowings, including commercial paper, credit facilities, note financings or other borrowings.

 Edison International Income Taxes
 Net Operating Loss and Tax Credit Carryforwards
 Edison International has approximately $3.6 billion of tax effected net operating losses and tax credit carryforwards at December 31, 2024 (after excluding $107 million of Capistrano Wind attributes and offsetting $397 million of unrecognized tax benefits), which are available to offset future consolidated tax liabilities.
 See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for further information regarding taxes payable to Capistrano Wind.
 Inflation Reduction Act of 2022
 The IRA imposes a 15% corporate alternative minimum tax ("CAMT") on adjusted financial statement income ("AFSI") of corporations with average AFSI exceeding $1.0 billion over a specified 3-year period. The CAMT was effective beginning January 1, 2023. Based on the current interpretation of the law and historical financial data, Edison International estimates that it will exceed the $1.0 billion threshold and be subject to CAMT on its consolidated federal tax returns beginning in 2026. SCE expects to be subject to CAMT on its stand-alone Federal return beginning in 2026.

 The law also includes significant extensions, expansions, and enhancements of numerous energy-related investment tax credits, as well as creating new credits applicable to electricity production which may apply to SCE's capital expenditures. Under the IRA, as of December 31, 2024, SCE generated investment tax credits of approximately $231 million related to two utility owned storage projects, which will be recognized and returned to customers, as the credits are utilized.

 Historical Cash Flows

 SCE

 2024
 2023
 2022

 $
 5,383
 $
 3,681
 $
 3,319

 1,182
 2,724

 Net cash used in investing activities
 (5,530)
 (5,231)
 (5,557)

 Net increase (decrease) in cash, cash equivalents and restricted cash

 $
 $
 (368)
 $

 Net Cash Provided by Operating Activities
 The following table summarizes major categories of net cash provided by operating activities as provided in more detail in SCE's consolidated statements of cash flows for 2024, 2023, and 2022:

 Change

 2024
 2023
 2022
 2024/2023

 $
 1,794
 $
 1,597
 $

 Non-cash items1

 3,013
 2,979
 2,701

 Subtotal
 4,807
 4,576
 3,655
 $

 Contributions to Wildfire Insurance Fund
 (95)
 (95)
 (95)
 —

 Changes in cash flow resulting from working capital2

 (221)
 (762)

 Regulatory assets and liabilities
 1,219
 (51)

 Wildfire related claims3

 (397)
 (410)
 (56)

 Other noncurrent assets and liabilities4

 (204)
 (461)

 $
 5,383
 $
 3,681
 $
 3,319
 $
 1,702

 1Non-cash items include depreciation and amortization, allowance for equity during construction, impairment and other income, Wildfire Insurance Fund amortization expense, deferred income taxes, and other.
 2Changes in working capital items include receivables, accrued unbilled revenue, inventory, amortization of prepaid expenses, accounts payable, tax receivables and payables, derivative assets and liabilities, and other current assets and liabilities.
 3The amount in 2024 represents payments of $779 million for 2017/2018 Wildfire/Mudslide Events and $361 million for Other Wildfire Events, partially offset by an increase in wildfire estimated losses of $743 million. The amount in 2023 represents payments of $1.0 billion for 2017/2018 Wildfire/Mudslide Events and $190 million for Other Wildfire Events, partially offset by an increase in wildfire estimated losses of $814 million.
 4Includes nuclear decommissioning trusts. See "Nuclear Decommissioning Activities" below for further information. The amount in 2024 also includes cash received from customers to fund certain construction projects and cash received for a state incentive program to pass on to customers. The amount in 2023 also includes outflow from the increases in wildfire insurance receivables.
 Net cash provided by operating activities was impacted by the following:
 Net income and non-cash items increased in 2024 by $231 million primarily due to higher revenue authorized in Track 4 and an increase in the authorized rate of return resulting from the cost of capital adjustment mechanism, partially offset by higher interest expense.
 The net outflows in cash resulting from working capital were $221 million and $762 million in 2024 and 2023, respectively. Net cash outflows for both 2024 and 2023 were primarily due to increases in unbilled revenue and power procurement related receivables. The higher outflow in 2023 was also due to payments of power purchase contracts that had high gas prices from December 2022, as well as an increase in customer receivables due to various customer protection programs in place.

 Net cash provided by regulatory assets and liabilities, including changes in net over or undercollections recorded in balancing accounts, was $1,219 million and $576 million in 2024 and 2023, respectively. SCE has a number of balancing and memorandum accounts, which impact cash flows based on differences between timing of collection through rates and incurring expenditures. Cash inflows in 2024 and 2023 were both due to recovery of prior year undercollections. The higher inflow in 2024 compared to 2023 was driven by higher prior year undercollections implemented into rates in 2024, higher sales volume due to hotter weather in 2024, and higher overcollection from funds collected for customer-funded wildfire self-insurance in 2024.
 Net Cash Provided by Financing Activities
 The following table summarizes cash provided by financing activities for 2024, 2023, and 2022. Issuances of debt is discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."

 2024
 2023
 2022

 Issuances of long-term debt, net of discount and insurance costs
 $
 4,214
 $
 3,588
 $
 5,032

 Long-term debt repaid
 (2,201)
 (2,098)
 (385)

 Short-term debt borrowed
 —
 —

 Short-term debt repaid
 (386)
 (1,051)
 (1,543)

 Commercial paper financing, net
 (406)

 Preference stock issued, net of issuance cost
 —

 Preference stock redeemed
 (628)
 —
 —

 Capital contributions from Edison International Parent
 —
 1,400

 Payment of common stock dividends to Edison International Parent
 (1,440)
 (1,400)
 (1,300)

 Payment of preference stock dividends
 (168)
 (117)
 (110)

 Other
 (16)

 $
 $
 1,182
 $
 2,724

 Net Cash Used in Investing Activities
 Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Cash used in capital expenditures were $5.7 billion, $5.4 billion, and $5.8 billion for 2024, 2023, and 2022, respectively, primarily related to transmission, distribution and generation investments. SCE had a net redemption of nuclear decommissioning trust investments of $121 million, $180 million, and $123 million in 2024, 2023, and 2022, respectively. See "Nuclear Decommissioning Activities" below for further discussion.
 Nuclear Decommissioning Activities
 SCE's consolidated statements of cash flows include nuclear decommissioning activities, which are reflected in the following line items:

 2024
 2023
 2022

 Net cash used in operating activities:

 Net earnings from nuclear decommissioning trust investments

 $
 $
 $

 SCE's decommissioning costs
 (222)
 (229)
 (189)

 (182)
 (187)
 (111)

 Net cash provided by investing activities:

 Proceeds from sale of investments
 5,019
 4,597
 4,177

 Purchases of investments
 (4,898)
 (4,417)
 (4,054)

 Net cash (outflow) inflow
 $
 (61)
 $
 (7)
 $

 Net cash used in operating activities relates to interest and dividends less administrative expenses, taxes and SCE's decommissioning costs. Investing activities represent the purchase and sale of investments within the nuclear decommissioning trusts, including the reinvestment of earnings from nuclear decommissioning trust investments.
 Funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts. The net cash impact reflects timing of decommissioning payments ($222 million, $229 million, and 189 million in 2024, 2023, and 2022, respectively) and reimbursements to SCE from the nuclear decommissioning trust ($214 million, $222 million, and $201 million in 2024, 2023, and 2022, respectively). The net cash outflow in 2024 also primarily includes $19 million of tax benefits received and a $30 million disallowance under the 2021 NDCTP (For further details, see "—Decommissioning of San Onofre), both contributed by SCE to the decommissioning trust.

 The table below sets forth condensed historical cash flow from operations for Edison International Parent and Other, including intercompany eliminations.

 2024
 2023
 2022

 Net cash used in operating activities
 $
 (369)
 $
 (280)
 $
 (103)

 Net cash used in investing activities
 (6)
 (2)
 (17)

 Net (decrease) increase in cash, cash equivalents and restricted cash
 $
 (15)
 $
 (17)
 $

 Net Cash Used in Operating Activities
 Net cash used in operating activities increased by $89 million in 2024 compared to 2023, primarily due to cash outflows of $318 million in 2024 and $280 million in 2023 for interest and operating costs. Additionally, there was $51 million cash outflow in 2024 related to a California state income tax payment.
 Net Cash Provided by Financing Activities
 Net cash provided by financing activities was as follows:

 2024
 2023
 2022

 Dividends paid to Edison International common shareholders
 $
 (1,198)
 $
 (1,112)
 $
 (1,050)

 Dividends paid to Edison International preferred shareholders
 (88)
 (108)
 (99)

 Dividends received from SCE
 1,440
 1,400
 1,300

 Capital contributions to SCE
 (500)
 —
 (1,400)

 Receipt from stock option exercises

 Repurchase of common stock
 (200)
 —
 —

 Long-term debt issuance, net of discount and issuance costs
 1,042
 1,533

 Long-term debt repayments
 (500)
 (400)
 (700)

 Issuance of short-term debt
 —
 1,000

 Repayments of short-term debt
 (15)
 (1,356)
 —

 Preferred stock repurchased
 (28)
 (289)
 —

 Commercial paper financing, net

 Other
 (13)

 $
 $
 $

 Contractual Obligations and Contingencies

 Contractual Obligations
 SCE and Edison International Parent and Other have various contractual obligations, which are recorded as liabilities in the consolidated financial statements. Other items, such as certain purchase commitments and other executory contracts, are not recognized as liabilities in the consolidated financial statements but are required to be disclosed in the footnotes to the financial statements.
 For details on long-term debt, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
 Certain power purchase agreements which SCE entered into with independent power producers are treated as operating or finance leases. In addition, SCE has other operating lease obligations primarily related to vehicles, office space and other equipment. For further discussion, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" and "—Note 13. Leases."
 SCE also has other purchase obligations primarily related to maintaining reliability and expanding SCE's transmission and distribution system and nuclear fuel supply contracts. For further discussion, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies."
 Edison International Parent and Other and SCE have estimated contributions to the pension and PBOP plans. These amounts represent estimates that are based on assumptions that are subject to change. See "Notes to Consolidated Financial Statements—Note 9. Compensation and Benefit Plans" for further information.
 Edison International and SCE have a total net liability recorded for uncertain tax positions. Edison International and SCE cannot make reliable estimates of the cash flows by period due to uncertainty surrounding the timing of resolving these open tax issues with the tax authorities. See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for further information.
 For details on derivative obligations and asset retirement obligations, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments" and "—Note 1. Summary of Significant Accounting Policies," respectively.

 Contingencies
 Edison International's and SCE's material contingencies are discussed in "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies."

 Off-Balance Sheet Arrangements
 SCE has variable interests in power purchase contracts with variable interest entities. See "Notes to Consolidated Financial Statements—Note 3. Variable Interest Entities."

 MARKET RISK EXPOSURES
 Edison International's and SCE's primary market risks include fluctuations in interest rates, commodity prices and volumes, and counterparty credit. Derivative instruments are used to manage market risks including market risks to SCE's customers. For further discussion of market risk exposures, including commodity price risk, credit risk and interest rate risk, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments" and "—Note 4. Fair Value Measurements."

 Interest Rate Risk
 Edison International and SCE are exposed to changes in interest rates primarily as a result of financing, investing and borrowing activities used for liquidity purposes, and to fund business operations and capital investments. The nature and amount of Edison International's and SCE's long-term and short-term debt can be expected to vary as a result of future business requirements, market conditions and other factors. Fluctuations in interest rates can affect earnings and cash flows. Changes in interest rates may impact SCE's authorized rate of return for the period beyond 2025 through a CPUC cost of capital proceeding, see "Management Overview—Cost of Capital" and "Business—SCE—Overview of Ratemaking

 Process" for further discussion. The following table summarizes the increase or decrease to the fair value of long-term debt including the current portion, if the market interest rates were changed while leaving all other assumptions the same:

 Carrying Value
 10% Increase
 10% Decrease

 $
 35,583
 $
 33,160
 $
 31,845
 $
 34,596

 33,013
 31,315
 30,060
 32,684

 SCE:

 30,515
 27,994
 26,827
 29,267

 28,494
 26,712
 25,593
 27,930

 Commodity Price Risk
 SCE and its customers are exposed to the risk of a change in the market price of natural gas, electric power and transmission congestion. Due to regulatory mechanisms, exposure to commodity prices is not expected to impact earnings but may impact timing of cash flows. SCE's hedging program is designed to reduce exposure to variability in market prices related to SCE's purchases and sales of electric power and natural gas. As part of this program, SCE enters into energy options, swaps, forward arrangements, and congestion revenue rights ("CRRs"). The transactions are pre-approved by the CPUC or executed in compliance with CPUC-approved procurement plans. Therefore, SCE expects recovery of its related hedging costs, as well as procurement costs, through the ERRA balancing account or CPUC-approved procurement plans. For more details of the ERRA balancing account, see "Business—SCE—Overview of Ratemaking Process."
 Fair Value of Derivative Instruments
 The fair value of derivative instruments is included in the consolidated balance sheets unless subject to an exception under the applicable accounting guidance. Realized gains and losses from derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, accordingly, changes in the fair value of derivative instruments have no impact on earnings. SCE does not use hedge accounting for these transactions due to this regulatory accounting treatment. For further discussion on fair value measurements and the fair value hierarchy, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements."
 The fair value of outstanding derivative instruments used to mitigate exposure to commodity price risk was a net asset of $212 million and $91 million at December 31, 2024 and 2023, respectively.
 The following table summarizes the increase or decrease to the fair values of the net asset of derivative instruments included in the consolidated balance sheets, if the electricity prices or gas prices were changed while leaving all other assumptions constant:

 2024
 2023

 Increase in electricity prices by 10%
 $
 $

 Decrease in electricity prices by 10%
 (34)
 (26)

 Increase in gas prices by 10%

 Decrease in gas prices by 10%
 (1)
 (5)

 Investment Price Risk
 Edison International and SCE are subject to investment price risk due to securities held as investments in the nuclear decommissioning trust and various pension and other post-retirement benefit plan trusts.
 Nuclear Decommissioning Trust
 As of December 31, 2024, SCE's nuclear decommissioning trust investments include equity investments of $1.6 billion and fixed income investments of $2.6 billion. These investments are exposed to price fluctuations in equity markets and changes in interest rates. SCE's investment policies and CPUC requirements place limitations on the types and investment grade ratings of the securities that may be held by the nuclear decommissioning trust. These policies restrict the trust from holding alternative investments and limit the trust funds' exposures to investments in highly illiquid markets. Due to regulatory mechanisms, investment earnings and realized and unrealized gains and losses increase or decrease the trust assets and the related regulatory asset or liability, and do not materially affect earnings. For further discussion on the

 nuclear decommissioning trust investments, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements" and "—Note 10. Investments."
 PBOP and Pension Plan Assets
 The PBOP Plan and the Southern California Edison Company Retirement Plan Trust assets include investments in equity securities, U.S. treasury securities, other fixed-income securities, common/collective funds, mutual funds, other investment entities, foreign exchange and interest rate contracts, and partnership/joint ventures. These investments are exposed to price fluctuations in equity markets and changes in interest rates. The investment of plan assets is overseen by a fiduciary investment committee. Risk is managed through diversification among multiple asset classes, managers, styles, and securities. See "Notes to Consolidated Financial Statements—Note 9. Compensation and Benefit Plans" for additional information regarding investment strategy of plan assets.
 Contributions related to SCE employees made to SCE pension plan are anticipated to be recovered through CPUC-approved regulatory mechanisms.

 Credit Risk
 Credit risk exposure from counterparties for power and gas trading activities is measured as the sum of net accounts receivable (accounts receivable less accounts payable) and the current fair value of net derivative assets (derivative assets less derivative liabilities) reflected on the consolidated balance sheets. SCE enters into master agreements which typically provide for a right of set-off. Accordingly, SCE's credit risk exposure from counterparties is based on a net exposure under these arrangements. SCE manages the credit risk on the portfolio of counterparties based on credit ratings and other publicly disclosed information, such as financial statements, regulatory filings and press releases, to guide it in the process of setting credit levels, risk limits and contractual arrangements, including master netting agreements. Based on SCE's policies and risk exposures related to credit, SCE does not anticipate a material adverse effect on their financial statements as a result of counterparty nonperformance. At December 31, 2024, SCE's power and gas trading counterparty credit risk exposure was $110 million, 99.8% of which was associated with entities with an investment grade rating of A or higher. SCE assigns a credit rating to counterparties based on the lowest of a counterparty's S&P's, Moody's, and Fitch's rating.
 For more information related to credit risks, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments."

 CRITICAL ACCOUNTING ESTIMATES AND POLICIES
 The accounting policies described below are considered critical to obtaining an understanding of Edison International's and SCE's consolidated financial statements because their application requires the use of significant estimates and judgments by management in preparing the consolidated financial statements. Management estimates and judgments are inherently uncertain and may differ significantly from actual results achieved. Management considers an accounting estimate to be critical if the estimate requires significant assumptions and changes in the estimate or, the use of alternative estimates, could have a material impact on Edison International's and SCE's results of operations or financial position. For more information on Edison International's and SCE's accounting policies, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."

 Accounting for Contingencies
 Nature of Estimates Required. Edison International and SCE record loss contingencies when management determines that the outcome of future events is probable of occurring and when the amount of the loss can be reasonably estimated. Gain contingencies are recognized in the financial statements when they are realized.
 Key Assumptions and Approach Used. The determination of an accrual for a loss contingency is based on management judgment and estimates with respect to the likely outcome of the matter, including the analysis of different scenarios. Liabilities are recorded or adjusted when events or circumstances cause these judgments or estimates to change. In assessing whether a loss is a reasonable possibility, Edison International and SCE may consider the following factors, among others: the nature of the litigation, claim or assessment, opinions or views of legal counsel and other advisors, and the experience gained from similar cases. Edison International and SCE provide disclosures for material contingencies when there is a reasonable possibility that a loss or an additional loss may be incurred.
 Effect if Different Assumptions Used. Actual amounts realized upon settlement of contingencies may be different than amounts recorded and disclosed and could have a significant impact on the liabilities, revenue and expenses recorded on the consolidated financial statements. For a discussion of contingencies, guarantees, and indemnities, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies."

 Application to Wildfires
 As discussed in "Management Overview," wildfires in SCE's service area have caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers.
 The extent of legal liability for wildfire-related damages in actions against utilities depends on a number of factors, including whether the utility substantially caused or contributed to the damages and whether parties seeking recovery of damages will be required to show negligence in addition to causation. Final determinations of legal liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes and settlements may be reached before determinations of legal liability are ever made.
 Edison International and SCE have incurred material losses in connection with several wildfires. Estimated losses for wildfire litigation are based on a number of assumptions and are subject to change as additional information becomes available. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged. For instance, SCE will receive additional information with respect to damages claimed as the claims mediation and trial processes progress. Other factors that can cause actual losses incurred to be higher or lower than estimated include the ability to reach settlements and the outcomes of settlements reached through the ongoing claims mediation and trial processes, uncertainties related to the sufficiency of insurance held by plaintiffs, uncertainties related to the litigation processes, including whether plaintiffs will ultimately pursue claims, uncertainty as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of certain wildfires, and the uncertainty as to how these factors impact future settlements.
 For more information related to the loss contingencies of the wildfires, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

 Rate Regulated Enterprises
 Nature of Estimate Required. SCE follows the accounting principles for rate-regulated enterprises which are required for entities whose rates are set by regulators at levels intended to recover the estimated costs of providing service, plus a return on net investment, or rate base. Regulators may also impose penalties or grant incentives. Due to timing and other differences in the collection of revenue, these accounting principles allow a cost that would otherwise be charged as an expense by an unregulated entity to be capitalized as a regulatory asset if it is probable that such cost is recoverable through future rates; conversely the accounting principles require creation of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. In addition, SCE recognizes revenue and regulatory assets from alternative revenue programs, which enables the utility to adjust future rates in response to past activities or completed events, if certain criteria are met.
 Accounting principles for rate-regulated enterprises also require recognition of an impairment loss if it becomes probable that the regulated utility will abandon a plant investment or the cost of a recently completed plant will be disallowed for ratemaking purposes, and a reasonable estimate of the amount of the disallowance can be made.
 Key Assumptions and Approach Used. SCE's management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to SCE or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. Using these factors, management has determined that existing regulatory assets are probable of future recovery or settlement, and regulatory liabilities are properly identified. This determination reflects the current regulatory climate and is subject to change in the future. SCE also considers whether any plant investments are probable of abandonment or disallowance.
 Effect if Different Assumptions Used. Significant management judgment is required to evaluate the anticipated recovery of regulatory assets and plant investments, the recognition of incentives and revenue subject to refund, as well as the anticipated cost of regulatory liabilities or penalties. If future recovery of costs ceases to be probable, all or part of the regulatory assets and/or plant investments would have to be written off against current period earnings, and additional regulatory liabilities would have to be recognized. At December 31, 2024, the consolidated balance sheets included regulatory assets of $11.6 billion and regulatory liabilities of $11.5 billion. If different judgments were reached on recovery of costs and timing of income recognition, SCE's earnings may vary from the amounts reported.
 Application to Southern California Wildfires
 Application to pre-AB 1054 fires
 Regulatory recovery of SCE's losses realized in connection with the 2017/2018 Wildfire/Mudslide Events in excess of available insurance is subject to approval by regulators. Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates.

 SCE utilizes objectively determinable evidence to form its view on probability of future recovery. The only directly comparable precedent, in which a California investor-owned utility sought recovery for uninsured wildfire claims related costs and the CPUC made a prudency determination, is SDG&E's requests for cost recovery related to 2007 wildfire activity. The FERC allowed recovery of all FERC-jurisdictional wildfire claims related costs, while the CPUC rejected recovery of all CPUC-jurisdictional wildfire claims related costs based on a determination that SDG&E did not meet the CPUC's prudency standard.
 In January 2025, the CPUC approved the TKM Settlement Agreement and closed the proceeding. However, the CPUC did not make a determination regarding SCE's prudency when it approved the TKM Settlement Agreement. Therefore, notwithstanding CPUC approval of the TKM Settlement Agreement, SCE believes that the CPUC's interpretation and application of the prudency standard to SDG&E continues to create substantial uncertainty regarding how that standard will be applied to an investor-owned utility in wildfire cost-recovery proceedings for fires ignited prior to July 12, 2019. Consequently, SCE is unable to estimate the uninsured CPUC-jurisdictional claims related costs related to the Woolsey Fire or Creek Fire, both pre-AB 1054 events, that are probable of future recovery, and will not record a regulatory asset for recoveries related to the Woolsey Fire or Creek Fire in connection with the approval of the TKM Settlement Agreement. SCE will continue to evaluate the facts and circumstances of the pre-AB 1054 cost recovery proceeding to determine if and when a regulatory asset for pre-AB 1054 events may be recorded.
 Through the operation of its FERC Formula Rate, and based upon the precedent established in SDG&E's recovery of FERC-jurisdictional wildfire-related costs, SCE believes it is probable it will recover its FERC-jurisdictional wildfire and mudslide related costs and has recorded total expected recoveries within the FERC balancing account.
 Application to post-AB-1054 Other Wildfire Events
 Management judgment is required to assess the probability of recovery of SCE's losses realized, in excess of available insurance, in connection with wildfires ignited after the adoption of AB 1054 in July 2019.
 The CPUC and FERC may not allow SCE to recover uninsured losses through electric rates if it is determined that such losses were not reasonably or prudently incurred. On July 12, 2019, AB 1054 clarified that the CPUC must allow recovery of costs and expenses arising from a covered wildfire if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken in good faith under similar circumstances, at the relevant point in time, and based on the information available at that time. Further, utilities with a valid safety certification at the time of the relevant wildfire will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates "serious doubt" as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to dispel that doubt and prove its conduct was prudent. The serious doubt standard in AB 1054 is modeled after the FERC cost recovery standard. SCE evaluates the probability of recovery of costs related to the Other Wildfire Events that ignited after the adoption of AB 1054 in the context of the prudency standard laid out by AB 1054 above, including how the FERC applies the serious doubt standard. SCE's evaluation also relies on its status as a holder of a valid safety certification, facts and other evidence known to date related to the ignition, and any regulatory decisions illustrating the interpretation and/or application of the prudency framework under AB 1054, which as of December 31, 2024, has not been applied by the CPUC to an actual cost recovery application filed by any California investor-owned utility. SCE also considers which costs are eligible for recovery based on precedent from other CPUC cost recovery proceedings. Management's assessment of the probability of recovery may change, related to changes in any of these factors in the future.
 See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" for further discussion of regulatory assets recorded for wildfire as of December 31, 2024.

 Nature of Estimates Required. As part of the process of preparing its consolidated financial statements, Edison International and SCE are required to estimate income taxes for each jurisdiction in which they operate. This process involves estimating actual current period tax expense together with assessing temporary differences resulting from differing treatment of items, such as depreciation, for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included within Edison International's and SCE's consolidated balance sheets, including net operating loss and tax credit carryforwards. Certain estimates and assumptions are required to determine whether deferred tax assets can and will be utilized in future periods. Based on currently enacted tax laws, Edison International expects to generate sufficient taxable income to fully utilize all loss and credit carryovers set to expire beyond 2024.
 Edison International and SCE take certain tax positions they believe are in accordance with the applicable tax laws. However, these tax positions are subject to interpretation by the Internal Revenue Service, state tax authorities and the courts. Edison International and SCE determine uncertain tax positions in accordance with the authoritative guidance.

 Key Assumptions and Approach Used. In determining whether it is more likely than not that all or some portion of net operating loss and tax credit carryforwards can be utilized, management analyzes the trend of GAAP earnings and then estimates the impact of future taxable income, reversing temporary differences and available prudent and feasible tax planning strategies based on currently enacted tax laws.
 Accounting for tax obligations requires management judgment. Edison International's and SCE's management use judgment in determining whether the evidence indicates it is more likely than not, based solely on the technical merits, that a tax position will be sustained, and to determine the amount of tax benefits to be recognized. Judgment is also used in determining the likelihood a tax position will be settled and possible settlement outcomes. In assessing uncertain tax positions Edison International and SCE consider, among others, the following factors: the facts and circumstances of the position, regulations, rulings, case law, opinions or views of legal counsel and other advisers, and the experience gained from similar tax positions. Edison International and SCE evaluate uncertain tax positions at the end of each reporting period and make adjustments when warranted based on changes in fact or law.
 Effect if Different Assumptions Used. Should a change in facts or circumstances, including a change in enacted tax legislation, lead to a change in judgment about the ultimate realizability of a deferred tax asset, Edison International and SCE would record or adjust the related valuation allowance in the period that the change in facts and circumstances occurs, along with a corresponding increase or decrease in the provision for income taxes.
 Actual income taxes may differ from the estimated amounts which could have a significant impact on the liabilities, revenue, and expenses recorded in the financial statements. Edison International and SCE continue to be under audit or subject to audit for multiple years in various jurisdictions. Significant judgment is required to determine the tax treatment of particular tax positions that involve interpretations of complex tax laws. Such liabilities are based on judgment and a final determination could take many years from the time the liability is recorded. Furthermore, settlement of tax positions included in open tax years may be resolved by compromises of tax positions based on current factors and business considerations that may result in material adjustments to income taxes previously estimated. For a discussion of current and deferred taxes, net operating losses and tax credit carryforwards, accounting for uncertainty in income taxes, unrecognized tax benefits, and tax disputes, see "Notes to Consolidated Financial Statements—Note 8. Income Taxes."

 Nuclear Decommissioning – Asset Retirement Obligation
 Key Assumptions and Approach Used. San Onofre Units 1, 2, and 3 decommissioning cost estimates are updated in each NDCTP and when there are material changes to the timing or amount of estimated future cash flows. Palo Verde decommissioning cost estimates are updated by the operating agent, Arizona Public Services, every three years and when there are material changes to the timing or amount of estimated future cash flows. SCE estimates that it will spend approximately $7.6 billion, undiscounted through 2098, to decommission its nuclear facilities.
 The current ARO estimates for San Onofre and Palo Verde are based on:
 • Decommissioning Costs. The estimated costs for labor, material, equipment and other, and low-level radioactive waste costs are included in each of the NRC decommissioning stages: license termination, site restoration and spent fuel storage. The liability to decommission SCE's nuclear power facilities is based on a 2024 decommissioning study, filed as part of the 2024 NDCTP, for San Onofre Unit 1, 2, and 3 and a 2023 decommissioning study for Palo Verde.
 • Escalation Rates. Annual escalation rates are used to convert the decommissioning cost estimates in base year dollars to decommissioning cost estimates in future-year dollars. Escalation rates are primarily used for labor, material, equipment, and low-level radioactive waste burial costs. SCE's current estimates are based upon SCE's decommissioning cost methodology used for ratemaking purposes. Average escalation rates range from 2.1% to 7.5% (depending on the cost element) annually.
 • Timing. Initial decommissioning activities at San Onofre Unit 1 started in 1999 and at Units 2 and 3 in 2013. Cost estimates for San Onofre Units are currently based on completion of decommissioning activities by 2056. Cost estimates for Palo Verde are based on an assumption that decommissioning will commence promptly after the current NRC operating licenses expire. The Palo Verde 1, 2, and 3 operating licenses currently expire in 2045, 2046, and 2047, respectively.
 • Spent Fuel Dry Storage Costs. Cost estimates, including the impact of escalations, are based on an assumption that the U.S. Department of Energy will begin to take spent fuel from the nuclear industry in 2034 and will remove the last spent fuel from the San Onofre and Palo Verde sites by 2054 and 2097, respectively.
 • Changes in Decommissioning Technology, Regulation and Economics. The current cost studies assume the use of current technologies under current regulations and at current cost levels.

 See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" for further discussion of the plans for decommissioning of San Onofre.
 Effect if Different Assumptions Used. The ARO for decommissioning SCE's nuclear facilities was $2.1 billion as of December 31, 2024, based on the most recent decommissioning studies performed and the subsequent cost estimate updates. Changes in the estimated costs, execution strategy or timing of decommissioning, or in the assumptions and judgments by management underlying these estimates, could cause material revisions to the estimated total cost to decommission these facilities which could have a material effect on the recorded liability.
 The following table illustrates the increase to the ARO liability if the cost escalation rate was adjusted while leaving all other assumptions constant:

 Increase to ARO at

 Uniform increase in escalation rate of 1 percentage point
 $

 The increase in the ARO liability driven by an increase in the escalation rate would result in a decrease in the regulatory liability for recoveries in excess of ARO liabilities. As of December 31, 2024, the regulatory liability for recoveries in excess of ARO liabilities was $1.7 billion.

 Pensions and Postretirement Benefits Other than Pensions
 Nature of Estimate Required. Authoritative accounting guidance requires companies to recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets and liabilities in the balance sheet; the assets and/or liabilities are normally offset through other comprehensive income (loss). In accordance with authoritative guidance for rate-regulated enterprises, regulatory assets and liabilities are recorded instead of charges and credits to other comprehensive income (loss) for its postretirement benefit plans that are recoverable in utility rates. Edison International and SCE have a fiscal year-end measurement date for all of their postretirement plans.
 Key Assumptions of Approach Used. Pension and other postretirement benefit obligations and the related effects on results of operations are calculated using actuarial models. Two critical assumptions, discount rate and expected return on assets, are important elements of plan expense, and the discount rate is important to liability measurement. Other assumptions, which require management judgment, include the rate of compensation increases, and rates of retirement, turnover and termination. Additionally, health care cost trend rates are critical assumptions for postretirement health care plans. These critical assumptions are evaluated periodically and updated to reflect actual experience, as appropriate.
 As of December 31, 2024, Edison International's and SCE's pension plans had a $3.6 billion and $3.3 billion projected benefit obligation, respectively, and total 2024 expense for these plans was $27 million and $24 million, respectively. As of December 31, 2024, the accumulated benefit obligation for Edison International's and SCE's PBOP plans were $741 million and $737 million, respectively, and there were no expenses for Edison International's and SCE's PBOP plans for 2024. The majority of annual contributions made to SCE's pension and PBOP plan are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the related annual expense.
 Pension expense is recorded for SCE based on the amount funded to the trusts, as calculated using an actuarial method required for ratemaking purposes, in which the impact of market volatility on plan assets is recognized in earnings on a more gradual basis. Any difference between pension expense calculated in accordance with ratemaking methods and pension expense calculated in accordance with authoritative accounting guidance for pension is accumulated as a regulatory asset or liability, and is expected, over time, to be recovered from or returned to customers. As of December 31, 2024, this cumulative difference amounted to $132 million, meaning that the ratemaking method has recognized less in expense than the accounting method since implementation of authoritative guidance for employers' accounting for pensions in 1987, which was offset by a regulatory liability for the current funding level of SCE's pension plan.
 Edison International and SCE used the following critical assumptions to determine expense for pension and PBOP for 2024:

 Pension
Plans
 PBOP
Plans

 Discount rate1

 5.04
 %
 5.06
 %

 Expected long-term return on plan assets2

 6.75
 %
 4.88
 %

 Assumed health care cost trend rates3

 *
 6.50
 %

 *Not applicable to pension plans.
 1The discount rate enables Edison International and SCE to state expected future cash flows at a present value on the measurement date. Edison International and SCE select its discount rate by performing a yield curve analysis. This analysis determines the equivalent discount rate on projected cash flows by matching the timing and amount of expected future benefit payments to the corresponding yields from the Willis Towers Watson RATE: Link 10th – 90th percentile yield curve model on the measurement date.
 2To determine the expected long-term rate of return on pension plan assets, current and expected asset allocations are considered, as well as historical and expected returns on plan assets. A portion of PBOP trusts asset returns are subject to taxation, so the 5% rate of return on plan assets above is determined on an after-tax basis. Actual time-weighted, annualized returns on the pension plan assets were 5.6%, 5.2% and 6.6% for the one-year, five-year and ten-year periods ended December 31, 2024, respectively. Actual time-weighted, annualized returns on the PBOP plan assets were 3.5%, 1.8% and 4.3% over these same periods. Accounting principles provide that differences between expected and actual returns are recognized over the average future service of employees.
 3The health care cost trend rate gradually declines to 5.00% for 2029 and beyond.
 As of December 31, 2024, Edison International and SCE had unrecognized net pension gains of $138 million and $120 million, respectively, and unrecognized PBOP gains of $1.5 billion. The unrecognized pension and PBOP gains primarily consisted of the cumulative impact of the increased discount rates on the respective benefit obligations and the cumulative difference between the expected and actual rate of return on plan assets. Of these deferred gains, $133 million of SCE's pension gains and $1.5 billion of SCE's PBOP gains are recorded as regulatory liabilities, respectively, and are expected to be amortized to expense over the expected future service of the employees (subject to regulatory adjustment) or refunded to ratepayers at the termination or completion of the plan.
 Edison International's and SCE's pension and PBOP plans are subject to limits established for federal tax deductibility. SCE funds its pension and PBOP plans in accordance with amounts allowed by the CPUC. Executive pension plans have no plan assets.
 Effect if Different Assumptions Used. Changes in the estimated costs or timing of pension and other postretirement benefit obligations, or the assumptions and judgments used by management underlying these estimates, could have a material effect on the recorded expenses and liabilities.
 The following table summarizes the increase or decrease to projected benefit obligation for pension and the accumulated benefit obligation for PBOP if the discount rate were changed while leaving all other assumptions constant:

 SCE

 Increase in
discount rate
by 1%
 Decrease in
discount rate
by 1%
 Increase in
discount rate
by 1%
 Decrease in
discount rate
by 1%

 Change to projected benefit obligation for pension
 $
 (123)
 $
 $
 (100)
 $

 Change to accumulated benefit obligation for PBOP
 (69)
 (69)

 A one percentage point increase in the expected rate of return on pension plan assets would decrease Edison International's and SCE's current year expense by $35 million and $33 million, respectively, and a one percentage point increase in the expected rate of return on PBOP plan assets would decrease both Edison International's and SCE's current year expense by $23 million.

 Contributions to the Wildfire Insurance Fund
 Nature of Estimates Required. At December 31, 2024, Edison International and SCE have a $1.9 billion long-term asset and a $138 million current asset reflected as "Wildfire Insurance Fund contributions" in the consolidated balance sheets for the initial $2.4 billion contribution made during 2019 and the present value of annual contributions SCE committed to make to the Wildfire Insurance Fund, reduced by amortization. At December 31, 2024, a long-term liability of $363 million has been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contributions. Contributions were discounted to the present value using US treasury interest rates at the date SCE committed to participate in the Wildfire Insurance Fund.

 Management concluded it would be most appropriate to account for the contributions to the Wildfire Insurance Fund similar to prepaid insurance, ratably allocating the expense to periods based on an estimated period of coverage.
 Key Assumptions and Approach Used. The Wildfire Insurance Fund does not have a defined life. Instead, the Wildfire Insurance Fund will terminate when the administrator determines that the fund has been exhausted. Management reassesses the period of coverage of the fund at least annually in the first quarter each year and adjustments are applied on a prospective basis. The determination of the correct period in which to record an expense in relation to contributions to the Wildfire Insurance Fund depends, among other factors, on management's assessment of: the future occurrence and magnitude of wildfires; the involvement of SCE, or other electrical corporations which could access the Wildfire Insurance Fund, in the ignition of those fires; the probable future outcomes of CPUC cost recovery proceedings for wildfire claims, which may require reimbursement of the fund by electrical corporations; and the use of the contributions by the administrator of the Wildfire Insurance Fund. Further information regarding these factors may become available due to the actions of the fund administrator, or other entities, which could require management to reassess the period of coverage.
 Edison International and SCE assess the Wildfire Insurance Fund contribution asset for impairment each reporting period. An impairment will be recorded if the Wildfire Insurance Fund contribution asset exceeds SCE's ability to benefit from the remaining coverage provided by the Wildfire Insurance Fund.
 In January 2024, Edison International and SCE used Monte Carlo simulations for the annual assessment to estimate the period of coverage of the fund. This assessment was based on ten years (2014 – 2023) of historical data from wildfires caused by electrical utility equipment to estimate expected loss, resulting in an estimated fund life of 20 years from the date SCE committed to participate in the Wildfire Insurance Fund. The details of the operation of the Wildfire Insurance Fund and estimates related to claims by SCE, PG&E, and SDG&E against the fund have been applied to the expected loss simulations to estimate the period of coverage of the fund. The most sensitive inputs to the estimated period of coverage are the expected frequency of wildfire events caused by investor-owned utility electrical equipment and the estimated costs associated with those forecasted events. These inputs are most affected by the historical data used in estimating expected losses. Using a 17-year period (2007 – 2023) of historical data would further increase the period of coverage. There were fires in the service area of SCE, PG&E and SDG&E since the inception of the Wildfire Insurance Fund, including fires for which the cause is unknown, which may in the future be determined to be covered by the Wildfire Insurance Fund and have not been reflected or estimated at this time. As of the date of this filing, SCE is continuing to perform its annual assessment for 2025 to reassess its estimate of the life of the Wildfire Insurance Fund.
 Effect if Different Assumptions Used. Changes in the estimated life of the insurance fund, including impairment of the fund, could have a material impact on the expense recognition.

 NEW ACCOUNTING GUIDANCE
 New accounting guidance is discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—New Accounting Guidance."

 RISK FACTORS

 RISKS RELATING TO EDISON INTERNATIONAL
 Edison International's liquidity and ability to pay dividends depends on its ability to borrow funds, access to bank and capital markets, monetization of tax benefits held by Edison International, and SCE's ability to pay dividends and tax allocation payments to Edison International. Edison International is a holding company and, as such, it has no material operations of its own. Edison International's ability to meet its financial obligations, make investments, and to pay dividends on its common stock is primarily dependent on the earnings and cash flows of SCE and SCE's ability to make upstream distributions. If SCE does not make upstream distributions to Edison International and Edison International is unable to access the bank and capital markets on reasonable terms, Edison International may be unable to continue to pay dividends to its shareholders or meet its financial obligations.
 Prior to paying dividends to Edison International, SCE has financial and regulatory obligations that must be satisfied, including, among others, debt service and preference stock dividends. Further, Edison International and SCE cannot pay dividends if California law requirements for the declaration of dividends are not met. For information on CPUC and California law requirements related to the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." SCE may also owe tax-allocation payments to Edison International under applicable tax-allocation agreements.
 Edison International's ability to obtain financing, as well as its ability to refinance debt and make scheduled payments of principal and interest, are dependent on numerous factors, including its levels of indebtedness, maintenance of acceptable credit ratings, financial performance, liquidity and cash flow, and other market conditions. In addition, the factors affecting

 SCE's business will impact Edison International's ability to obtain financing. Edison International's inability to borrow funds from time to time could have a material effect on Edison International's liquidity and operations.
 See "Risks Relating to Southern California Edison Company" below for further discussion.

 RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY

 Regulatory and Legislative Risks
 SCE's financial results depend upon its ability to recover its costs and to earn a reasonable rate of return on capital investments in a timely manner from its customers through regulated rates.
 SCE's ongoing financial results depend on its ability to recover its costs from its customers, including the costs of electricity purchased for its customers, through the rates it charges its customers as approved by the CPUC and FERC. SCE's financial results also depend on its ability to earn a reasonable return on capital, including long-term debt and equity. SCE's ability to recover its costs and earn a reasonable rate of return can be affected by many factors, including the time lag between when costs are incurred and when those costs are recovered in customers' rates and differences between the forecast or authorized costs embedded in rates (which are set on a prospective basis) and the amount of actual costs incurred.
 The CPUC or the FERC may not allow SCE to recover costs on the basis that such costs were not reasonably or prudently incurred or for other reasons. Further, SCE may incur expenses before the relevant regulatory agency approves the recovery of such costs. For example, SCE has incurred, and expects to further incur, wildfire mitigation expenses before it is clear whether such costs will be recoverable from customers. Also, the CPUC may deny recovery of costs incurred by SCE, including uninsured wildfire-related costs, if the CPUC determines that SCE was not prudent. For further information on recovery of uninsured wildfire-related costs see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs" and "Management Overview—Southern California Wildfires and Mudslides" in the MD&A. In addition, while SCE supports California's environmental goals, it may be prevented from fully executing on its strategy to support such goals by regulatory delay or lack of approval of cost-recovery for the costs of such strategic actions and electrification programs from the relevant regulatory agencies, including as a result of customer affordability concerns. For example, the CPUC issued a decision denying SCE's Building Electrification Program Application, citing, among other things, a desire to avoid increasing rates.
 SCE's CPUC authorized return on investment is established by multiplying an authorized rate of return, determined by the CPUC in standalone cost of capital proceedings, by SCE's authorized CPUC rate base. SCE's CPUC-authorized cost of capital is subject to potential adjustment should interest rates move substantially in years between cost of capital proceedings. SCE's authorized return on its transmission assets is established by multiplying an authorized rate of return, determined by the FERC, by SCE's transmission rate base. For further information see "Business—SCE—Overview of Ratemaking Process."
 SCE's capital investment plan, increasing procurement of renewable power and energy storage, inflation, commodity price volatility, increasing self-generation, load departures to CCAs or Electric Service Providers, and increasing environmental regulations, among other things, collectively place continuing upward pressure on customer rates. As customer rates increase, the CPUC may face greater pressure to approve lesser amounts in SCE's ratemaking or cost recovery proceedings. To relieve some of this upward rate pressure, the CPUC may authorize lower revenues, or increase the period over which SCE is allowed to recover amounts, or disallow the recovery of SCE's cost which could impact SCE's ability to recover its operating costs timely or at all. If SCE is unable to obtain a sufficient rate increase or modify its rate design to recover its costs and an adequate return on capital in rates in a timely manner, its financial condition and results of operations could be materially affected.
 SCE is subject to extensive regulation and the risk of adverse regulatory and legislative decisions, delays in regulatory or legislative decisions, and changes in applicable regulations or legislation.
 SCE operates in a highly regulated environment. SCE's business is subject to extensive federal, state and local energy, environmental and other laws and regulations. Among other things, the CPUC regulates SCE's retail rates and capital structure, and the FERC regulates SCE's wholesale rates and capital structure. The NRC regulates the decommissioning of San Onofre in addition to the local and state agencies that require permits. The construction, planning, siting and operation of SCE's power plants, energy storage projects, and transmission lines in California are also subject to regulation by the CPUC and other local, state and federal agencies.
 SCE must periodically apply for licenses and permits from these various regulatory authorities, including environmental regulatory authorities, and must abide by their respective rules, regulations and orders. Should SCE be unsuccessful in obtaining necessary licenses or permits or should these regulatory authorities initiate any investigations or enforcement actions or impose fines, penalties or disallowances on SCE, SCE may be prevented from executing its strategy and its

 business could be materially affected. The process of obtaining licenses and permits from regulatory authorities may be delayed or defeated by opponents and such delay or defeat could have a material effect on SCE's business.
 The Wildfire Insurance Fund and other provisions of AB 1054 may not be sufficient or effectively mitigate the significant risk faced by California investor-owned utilities related to liability for damages arising from catastrophic wildfires where utility facilities are a substantial cause, which could have a detrimental effect on SCE's business and financial condition. The effectiveness of AB 1054 to mitigate the wildfire-related risk faced by SCE is conditioned in part on the performance of OEIS and various entities formed under AB 1054 and related legislation to, among other things, administer the Wildfire Insurance Fund, approve WMPs, issue safety certifications, oversee and enforce compliance with wildfire safety standards, and develop metrics to reduce risk and measure compliance with risk reduction.
 In addition, CPUC approval is required to recover the costs SCE is incurring to strengthen its wildfire mitigation and prevention efforts described in SCE's WMPs. See "Business—Southern California Wildfires" and "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings" in the MD&A.
 In addition, existing regulations may be revised or re-interpreted and new laws and regulations may be adopted or become applicable to SCE, or its facilities or operations, in a manner that may have a detrimental effect on SCE's business or result in significant additional costs. In addition, regulations adopted via the public initiative or legislative process may apply to SCE, or its facilities or operations, in a manner that may have a detrimental effect on SCE's business or result in significant additional costs.
 SCE's energy procurement activities are subject to regulatory and market risks, including availability, that could materially affect its financial condition and liquidity.
 SCE obtains energy, capacity, environmental credits and ancillary services needed to serve its customers from its own generating plants and through contracts with energy producers and sellers. California law and CPUC decisions allow SCE to recover, through the rates it is allowed to charge its customers, reasonable procurement costs incurred in compliance with an approved procurement plan. Nonetheless, SCE's cash flows remain subject to volatility primarily resulting from changes in commodity prices, including as a result of gas supply constraints. Additionally, significant and prolonged gas use restrictions may adversely impact the reliability of the electric grid if critical generation resources are limited in their operations. For further information, see "Business—SCE—Purchased Power and Fuel Supply." SCE is also subject to the risks of unfavorable or untimely CPUC decisions about the compliance with SCE's energy procurement plan and the reasonableness of certain procurement-related costs.
 SCE may not be able to hedge its risk for commodities on economic terms or fully recover the costs of hedges through the rates it is allowed to charge its customers, which could materially affect SCE's liquidity and results of operations, see "Market Risk Exposures" in the MD&A.

 Operating Risks
 Damage claims against SCE for wildfire-related losses may materially affect SCE's financial condition and results of operations.
 Prolonged drought conditions and shifting weather patterns in California resulting from climate change as well as, among other things, buildup of dry vegetation in areas severely impacted by years of historic drought and lack of adequate clearing of hazardous fuels by responsible parties have increased the duration of the wildfire season and the risk of severe wildfire events.
 Severe wildfires and urban development in and near high fire risk areas in California have given rise to large damage claims against California utilities for fire-related losses alleged to be the result of utility practices and/or the failure of electric and other utility equipment. Catastrophic wildfires can occur in SCE's service area even if SCE effectively implements its WMPs. California courts have previously found utilities to be strictly liable for property damage, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. An inability to recover uninsured wildfire-related costs could materially affect SCE's business, financial condition and results of operations. For example, if SCE is unable to, or believes that it may be unable to, recover damages related to catastrophic wildfires through insurance, the Wildfire Insurance Fund (which is only available for fires ignited after July 12, 2019) or electric rates, or access the bank and capital markets on reasonable terms, SCE may not have sufficient cash or equity to pay dividends or may be restricted from declaring such dividends because it does not meet CPUC or California law requirements related to the declaration of dividends. For information on the California law requirements on the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." Also see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

 Edison International's and SCE's costs of accessing capital markets has increased due to the risks associated with wildfires in Southern California. Edison International's and SCE's access to the bank and capital markets could also be constrained and/or the costs of accessing those markets could increase further as a result of wildfire risk, including if Edison International's and/or SCE's credit ratings are downgraded or placed on negative watch due to concerns about Edison International and/or SCE's financial health as a result of wildfires.
 SCE's insurance coverage for wildfires may not be sufficient.
 SCE may not be able to recover uninsured losses (including amounts paid for self-insured retention and co-insurance) in electric rates. Additionally, SCE's contractors may experience coverage reductions and/or increased wildfire insurance costs in future years. For losses associated with claims occurring before the authorization of SCE's CPUC-authorized customer-funded self-insurance program, no assurance can be given that losses will not exceed the limits of SCE's or its contractors' insurance coverage. Losses which are not fully insured or cannot be recovered from contractors, through the Wildfire Insurance Fund or electric rates, including any such losses that exceed funds available through the Wildfire Insurance Fund and are ultimately not authorized to be recovered through rates, could materially affect Edison International's and SCE's financial condition and results of operations. For more information on wildfire insurance risk, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
 SCE may not effectively implement its wildfire mitigation plans.
 SCE will face a higher likelihood of catastrophic wildfires in its service area if it cannot effectively implement its WMPs. For example, SCE may not be able to effectively implement its WMPs if it experiences unanticipated difficulties relative to permitting delays, sourcing, engaging, and retaining effectively trained contract workers or procuring materials it needs to fulfill its mitigation obligations under the WMPs. In addition, if SCE does not have an approved WMP, SCE will not be issued a safety certification from the CPUC and will consequently not benefit from the presumption of prudency or the AB 1054 Liability Cap.
 The CPUC may assess penalties on SCE if it finds that SCE has failed to substantially comply with its WMP. In addition, SCE may be subject to mandated changes to, or restrictions on, its operational wildfire mitigation practices or be subject to regulatory fines and penalties or claims for damages and reputational harm if SCE does not execute its wildfire mitigation practices in compliance with applicable rules and regulations. SCE's wildfire mitigation practices include PSPS and using fast-curve settings. In addition, SCE has been and may be further subject to regulatory fines and penalties or claims for damages and reputational harm if it is determined that SCE has placed excessive or unreasonable reliance on PSPS or has failed to maintain compliance with notification and post event reporting requirements related to PSPS. For information regarding SCE's PSPS activities and related fines, see "Business—Southern California Wildfires—Public Safety Power Shutoff."
 SCE establishes the criteria under which it implements PSPS in its service area. To the extent SCE's criteria for implementing PSPS are not sufficient to mitigate the risk of wildfires during high wind events, SCE does not fully implement PSPS when criteria are met due to other overriding conditions or SCE's regulators or others mandate changes to, or restrictions on, its criteria or other operational PSPS practices, SCE will face a higher likelihood of catastrophic wildfires in its service area during high wind events. Similarly, if SCE is prohibited by the CPUC from implementing its desired fast-curve settings, SCE will face a higher likelihood of catastrophic wildfires in its service area.
 For more information on AB 1054, see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs—2019 Wildfire Legislation."
 SCE will not benefit from all of the features of AB 1054 if the Wildfire Insurance Fund is exhausted.
 Catastrophic wildfires could rapidly exhaust the Wildfire Insurance Fund and SCE will not be reimbursed by the Wildfire Insurance Fund or benefit from the AB 1054 Liability Cap if the fund has been exhausted as a result of damage claims previously incurred by SCE or the other participating utilities. AB 1054 does not have a mechanism for adding to or replenishing the Wildfire Insurance Fund.
 For more information on AB 1054, see "Business—Southern California Wildfires and Mudslides—Recovery of Wildfire-Related Costs—2019 Wildfire Legislation."
 Climate change exacerbated weather-related incidents and other natural disasters have and could continue to materially affect SCE's financial condition and results of operations.
 Weather-related incidents, including storms and events caused, or exacerbated, by climate change, such as wildfires, flooding and debris flows, and other natural disasters such as earthquakes can disrupt the generation and transmission of

 electricity, and can seriously damage the infrastructure necessary to deliver power to SCE's customers. The impacts of climate change continue to evolve and remain dynamic and unpredictable.
 Climate change has caused, and exacerbated, extreme weather events and wildfires in southern California, and wildfires could cause, among other things, public safety issues, property damage and operational issues. In addition, the risk of flooding and debris flows occurring as a result of rain may be heightened. For example, the Eaton Fire that ignited in Los Angeles County in January 2025 resulted in loss of life, property damage and loss of service and subsequent extreme weather events such as increased rain or flooding could further impact the affected areas. For more information on liabilities related to wildfire events, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
 Extreme heat events have and can continue to lead to prolonged widespread outages due to, among other things, state-wide capacity supply shortages or equipment failure. Extreme weather events can also lead to use of PSPS. Weather-related events, such as debris flows, flooding and melting of a significantly higher than normal snowpack, and earthquakes can cause over-topping or failure at an SCE dam resulting in a rapid release of water that could cause public safety issues, property damage and operational issues.
 Weather-related incidents and other natural disasters can lead to lost revenue and increased expense, including higher maintenance and repair costs, which SCE may not be able to recover from its customers. These incidents can also result in regulatory penalties and disallowances, particularly if SCE encounters difficulties in restoring power to its customers on a timely basis or if fire-related losses are found to be the result of utility practices and/or the failure of electric and other utility equipment. In addition, these occurrences could lead to significant claims for damages, including for loss of life and property damage. These occurrences could materially affect SCE's business, financial condition and results of operations, and the inability to restore power to SCE's customers could also materially damage the business reputation of SCE and Edison International.
 For additional information related to climate related risks, see "Business—Environmental Considerations—Environmental Risks."
 The generation, transmission and distribution of electricity are dangerous and involve inherent risks of damage to private property and injury to SCE's workforce and the general public.
 Electricity poses hazards for SCE's workforce and the general public should they come in contact with electrical current or equipment, including through energized downed power lines or if equipment malfunctions. In addition, the risks associated with the operation of transmission and distribution assets and power generation and storage facilities include public and workforce safety issues and the risk of utility assets causing or contributing to wildfires.
 Injuries and property damage caused by such events can subject SCE to liability that, despite the existence of insurance coverage, can be significant. In addition, SCE may be held responsible for the actions of its contractors and from time to time, SCE is named as a party in legal proceedings involving claims related to its contractors and their employees. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. Litigation and other legal processes are subject to inherent uncertainties, including, costs of litigation, unpredictable court or jury decisions, and the differing laws and sentiments regarding damage awards in regions where SCE operates.
 The CPUC has increased its focus on public safety with an emphasis on heightened compliance with construction and operating standards and the potential for penalties being imposed on utilities. Additionally, the CPUC has delegated to its staff the authority to issue citations to electric utilities, which can impose fines of up to $100,000 per violation per day (capped at a maximum of $8 million), pursuant to the CPUC's jurisdiction for violations of safety rules found in statutes, regulations, and the CPUC's General Orders. The CPUC also can issue fines greater than $8 million outside of the citation program. Such penalties and liabilities could be significant and materially affect SCE's liquidity and results of operations.
 SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage the risks inherent in constructing, operating, and maintaining its facilities and workforce.
 SCE's infrastructure is aging and could pose a risk to system reliability if not sufficiently maintained and expanded to meet load growth and electrification needs. In addition, as described above, natural disasters such as wildfires in SCE's service area can cause significant public safety issues, property damage and operational issues. SCE is engaged in a significant and ongoing infrastructure investment program. This investment program, which includes transmission projects and constructing utility owned storage to mitigate possible state-wide capacity shortages in 2025 and later years, has inherent operational risks and elevates the need for effective execution in SCE's activities. For example, utility owned storage facilities utilize lithium-ion battery technology that in certain circumstances can and have caused a thermal event that can ignite nearby materials, including other lithium-ion cells particularly when deployed in indoor facilities. SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage these risks as well as the risks inherent in constructing, operating, and maintaining its facilities, the operation of which can be hazardous and

 important for system reliability. SCE's inherent operating risks include such matters as the risks of human performance, availability of skilled workforce and workforce capabilities, contractor management, data and records accuracy, public opposition to infrastructure projects, delays, environmental remediation and mitigation costs, difficulty in estimating costs or in recovering costs that are above original estimates, system limitations and degradation, maintaining physical security of workforce and assets, maintaining cybersecurity of data and assets, and delays and interruptions in necessary supplies, including key components necessary for the timely construction of utility owned storage. For example, SCE's financial condition may be materially affected as a result of safety incidents, delays, permitting violations and violations of regulatory requirements, among other things, caused by SCE's failure to appropriately manage its contractor workforce or from contractual violations by SCE's contractors and the inability for SCE to recover through contractual indemnities or insurance held by the contractor. SCE's financial condition may also be materially affected as a result of data or records inaccuracies, for example, inaccurate records could lead to missing or delayed compliance with SCE's policies and regulatory requirements, and could contribute to safety incidents.
 SCE's financial condition and results of operations could also be materially affected if SCE is unable to attract, train and retain a qualified workforce, and provide safe working conditions for its workforce, including its operations and management personnel. Constrained labor market in California and nationally and SCE's relations with its unionized workforce also impact SCE's ability to maintain its workforce. For example, the increased electrification efforts in California and nationally have led to greater competition for certain skilled workers.
 There are inherent risks associated with owning and decommissioning nuclear power generation facilities and obtaining cost reimbursement, including, among other things, insufficiency of nuclear decommissioning trust funds, costs exceeding current estimates, execution risks, potential harmful effects on the environment and human health and the hazards of storage, handling and disposal of radioactive materials. Existing insurance and ratemaking arrangements may not protect SCE fully against losses from a nuclear incident.
 SCE funds decommissioning costs with assets that are currently held in nuclear decommissioning trusts. Based upon the financial performance of the nuclear decommissioning trust fund investments, as well as the resolution of a number of other uncertainties, assumptions and estimates, additional contributions to the nuclear decommissioning trust's funds may be required. If additional contributions to the nuclear decommissioning trust funds become necessary, recovery of any such additional funds through electric rates is subject to the CPUC's review and approval.
 The costs of decommissioning San Onofre are subject to reasonableness reviews by the CPUC. These costs may not be recoverable through regulatory processes or otherwise unless SCE can establish that the costs were reasonably incurred. In addition, SCE faces inherent execution risks including such matters as the risks of human performance, workforce capabilities, public opposition, permitting delays, and governmental approvals. Decommissioning costs ultimately incurred could exceed the current estimates and cost increases resulting from contractual disputes, delays in performance by DCG, elevated levels of inflation, or permitting delays, among other things, could cause SCE to materially overrun current decommissioning cost estimates and could materially impact the sufficiency of trust funds. See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" in the MD&A.
 Even though San Onofre is being decommissioned, the presence of spent nuclear fuel still poses a potential risk of a nuclear incident. Federal law limits public liability claims from a nuclear incident to the amount of available financial protection, which is currently approximately $16.3 billion for Palo Verde and $560 million for San Onofre. SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available of $500 million per site. In the case of San Onofre, the balance is covered by a U.S. Government indemnity. In the case of Palo Verde, the balance is covered by a loss sharing program among nuclear reactor licensees. There is no assurance that the CPUC would allow SCE to recover the required contribution made pursuant to this loss sharing program in the case of one or more nuclear incidents with claims that exceeded $500 million at a nuclear reactor which is participating in the program. If this public liability limit of $16.3 billion is insufficient, federal law contemplates that additional funds may be appropriated by Congress. There can be no assurance of SCE's ability to recover uninsured costs in the event the additional federal appropriations are insufficient. For more information on nuclear insurance risk, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Nuclear Insurance."
 SCE's distribution of water and propane gas on Catalina Island involves inherent risks of damage to private property and the environment and injury to employees and the general public.
 SCE owns and operates the water distribution system that serves Catalina Island, California and a propane gas distribution system that serves the City of Avalon on Catalina Island, California. Production, storage, treatment and distribution of water for human use and the transportation, storage, distribution and use of gas can be hazardous, and can cause damage to private property and the environment and injury to employees and the general public if equipment fails or does not perform as anticipated. For example, the risks of operating a water distribution system include the potential for burst pipes and water contamination and the risks of operating gas distribution system include the potential for gas leaks, fire or explosion. The risks related to SCE's operation of its water and gas distribution systems may be exacerbated due to aging

 infrastructure. SCE has, in the past, requested that the CPUC allow SCE to include certain water system costs in electric rates and may make similar requests for the water and gas systems in the future. If such requests are denied, significant costs may not be recoverable from customers. In addition, SCE may have to pay fines, penalties and remediation costs if it does not comply with laws and regulations in the operation of the water and gas distribution systems. An inability to recover costs associated with any such damages or injuries or any fines, penalties or remediation costs, from insurance or through electric rates, could materially affect SCE's business, financial condition and results of operations.

 Financing Risks
 As a capital-intensive company, SCE relies on access to the bank and capital markets. If SCE were unable to access these markets or the cost of financing were to substantially increase, its liquidity and operations could be materially affected.
 SCE regularly accesses the bank and capital markets to finance its activities and is expected to do so by its regulators as part of its obligation to serve its customers. SCE needs substantial capital for its ongoing infrastructure investment program and for financing wildfire related losses. SCE's ability to obtain financing, as well as its ability to refinance debt and make scheduled payments of principal and interest, are dependent on numerous factors, including SCE's levels of indebtedness, maintenance of acceptable credit ratings, financial performance, liquidity and cash flow, increases in interest rates and credit spreads due to inflationary pressures, and other market conditions. In addition, the actions of other California investor-owned utilities and legal, regulatory and legislative decisions impacting investor-owned utilities can affect market conditions and therefore, SCE's ability to obtain financing. SCE's inability to obtain additional capital from time to time could have a material effect on SCE's liquidity and operations.

 Competitive and Market Risks
 If SCE is unable to operate efficiently and to effectively and timely respond to the changes that the electricity industry is undergoing, as a result of increased load requirements, competition, technological advances, and changes to the regulatory environment, SCE's business model, financial condition and results of operations could be materially impacted.
 SCE's ability to efficiently operate and implement process changes has a direct impact on its ability to execute its strategy, its customer rates and affordability of electricity. Even if SCE's costs are recoverable, the necessary costs of operations and investments supporting safety, reliability, resilience and being ready to meet California's clean energy goals will negatively impact the affordability of SCE's customer rates, may cause reputational harm and cause increased load departures.
 Customers and third parties are increasingly deploying DERs, such as solar generation, energy storage, energy efficiency and demand response technologies. California's environmental policy objectives are accelerating the pace and scope of industry change. This change will require modernization of the electric distribution grid to, among other things, accommodate two-way flows of electricity and increase the grid's capacity to interconnect DERs. In addition, enabling California's clean energy economy goals will require sustained investments in grid modernization, renewable integration projects, energy efficiency programs, energy storage options and electric vehicle infrastructure. If SCE is unable to operate efficiently and adapt to these changes, its business model, its ability to execute on its strategy, and ultimately its financial condition and results of operations could be materially impacted.
 Customer-owned generation and load departures to CCAs or Electric Service Providers each reduce the amount of electricity that customers purchase from utilities and have the effect of increasing utility rates unless customer rates are designed to allocate the costs of the distribution grid across all customers that benefit from its use. For example, some customers in California who generate their own power are not currently required to pay all transmission and distribution charges and non-bypassable charges, subject to limitations, which results in increased costs for other customers. If there are not updates in regulations to further support the need for customers pay their share of transmission and distribution costs and non-bypassable charges, for example through a higher fixed charge, and the demand for electricity reduces so significantly that SCE is no longer effectively able to recover such costs from its customers, SCE's business, financial condition and results of operations will be materially impacted.
 In addition, the FERC has opened transmission development to competition from independent developers, allowing such developers to compete with incumbent utilities for the construction and operation of transmission facilities.
 For more information. See "Business—SCE—Competition."

 RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY

 Cybersecurity and Physical Security Risks
 Successful attacks on SCE information and operational technology systems and infrastructure could have a material impact on SCE's operations or financial condition
 Edison International and SCE systems, assets and personnel are targets for physical and cyber attacks. Regulators such as NERC and U.S. Government agencies, including the Departments of Defense, Homeland Security, and Energy, have increasingly stressed that threat sources continue to seek to identify and exploit vulnerabilities in the U.S. national electric grid and other critical energy infrastructures, and that such attacks and disruptions, both physical and cyber, are highly sophisticated and dynamic. Several U.S. Government agencies have highlighted the increasing risks related to physical and cybersecurity attacks, including ransomware attacks, related to the electric sector, including its supply chain, and that the risks may escalate during periods of heightened geopolitical tensions.
 SCE requires the uninterrupted use of sophisticated information and operational technology systems and infrastructure to monitor and operate the electric grid. In the regular course of SCE's business, it also handles a range of sensitive infrastructure, security, employee, customer, and business systems information. If SCE's information technology and operational technology systems' security were to be compromised by physical or electronic means or a critical system or technology failure were to occur without timely recovery, including failure of new technology to be implemented as designed, SCE could be unable to fulfill critical business functions and/or sensitive information could be misappropriated or compromised. Such events could result in violations of privacy and other laws, material financial loss to SCE and/or to its customers, loss of confidence in SCE's security risk management, customer dissatisfaction, and significant litigation and/or regulatory exposure, all of which could materially affect Edison International's and SCE's financial condition, operations, and the business reputation of Edison International and SCE.
 SCE's security program cannot prevent all attacks or incidents
 SCE's systems have experienced, and will continue to face, cyber and physical security events involving malicious code, unauthorized access attempts, vandalism and other illicit activities. No security program can completely shield its systems, infrastructure, and data from attacks, intrusions, or other catastrophic events that could result in their failure or reduced functionality. There is no guarantee that SCE's security program, including prevention, detection, mitigation, and remediation of risks, will prevent all future cyber and physical security incidents that could materially impact its operations or financial condition.
 SCE is not able to anticipate and prevent all physical and cyber attacks or information security breaches, and its investments in security resources, talent, and business practices may not be effective against all threat actors, particularly nation-state actors. Voluntary cybersecurity guidelines and practices cannot be applied to all businesses equally due to system capability, complexity, and resources for implementation. SCE's security tools and controls, including those supporting configuration management, identity and access management, network segmentation, and boundary defenses, may not fully protect against unauthorized access from internal and external threats. SCE's current security controls and defenses may also not protect against insider threats, including deliberate and unintentional actions (e.g., human error) and other emerging cybersecurity risks created by artificial intelligence, quantum computing, cyber skills shortages, and regulatory constraints.
 SCE's security program is prioritized based on known risks, available resources, and regulatory requirements, and therefore all SCE assets are not equally protected. For example, not all of SCE's information technology assets are inventoried, which could result in unmitigated vulnerabilities or slow the detection, investigation, and recovery of an incident. Known vulnerabilities in SCE's information technology and operational technology environments may not be remediated before an adversary could discover or exploit them. Attackers can also exploit new, unknown vulnerabilities (e.g., zero day) and vulnerabilities where a patch or other remediation measure is not yet available.
 SCE's transition to a more network-connected grid and increased deployment of new technologies increases the number of systems adversaries can target
 SCE's operations require the continuous availability and deployment of critical information and operational technology systems, sensitive customer and employee data and infrastructure information, all of which are targets for malicious actors. New cyber and physical threats arise as SCE moves to an increasingly digital electric grid. For example, SCE's grid modernization efforts and the transition to a more connected grid, including the integration of new technologies and increased networking of operational technology assets such as substations, increases the threat surface and potential vulnerabilities that an adversary can target. As new systems are developed or procured by SCE, software development practices may not comprehensively prevent the introduction of new software vulnerabilities. Additionally, certain existing or legacy information technology, operational technology, and communications infrastructure use less secure protocols or configurations.

 Vendors and other third parties may be used to target and attack SCE
 SCE interacts with a wide array of third parties and depends on vendors to provide it with products and services. Malicious actors may attack vendors to disrupt the services they provide to SCE, or to use those vendors as a conduit to attack SCE. SCE system data and architecture are also disclosed, either voluntarily or by mandate, to third parties and the public by regulators, employees, contractors, and vendors. This system data may be used by malicious actors to understand SCE's systems to prepare for a cyber or physical attack.
 The products and services provided by SCE's vendors may contain vulnerabilities or otherwise not adhere to SCE's enterprise cybersecurity standards (e.g., lack of encryption). Additionally, SCE's operational technology vendors have increasingly been targeted by threat actors. A compromise of equipment and/or exfiltration of SCE data, whether by physical or by electronic means, could result in loss or changes to confidential or sensitive information and interruption of business processes. For example, compromises to widely-used products and services may affect the supply chains of many industries, including companies in SCE's supply chain. While SCE vendors have experienced cybersecurity incidents, such incidents have not, to SCE's knowledge, resulted in a material impact to SCE to date.

 Global and Regional Risks
 Edison International's and SCE's financial condition and results of operations could be materially impacted by catastrophic, macroeconomic and geopolitical events that cause significant disruption to workforces, supply chains, economies, or societies on a regional, statewide, national or global basis.
 Edison International and SCE could be materially and adversely impacted by catastrophic, macroeconomic and geopolitical events, such as the effects of increased inflationary pressures and interest rates, potential economic downturns or recessions, geopolitical pressures, and pandemics and regional health emergencies. For example, the global spread of COVID-19, which was declared a pandemic by the World Health Organization in March 2020, created significant uncertainty, volatility and disruption globally that resulted in, among other things, disruption to supply chains, economies, and workforce and impacted the operations of Edison International and SCE. Additionally, the geopolitical developments involving the Russia-Ukraine conflict, China and the Middle East, could cause delays and disruptions in the supply chain and the availability and timely delivery of services, materials and components used in SCE's operations. Political changes following the United States presidential election could lead to changes in economic conditions or economic uncertainties in the United States and globally, including impacts to infrastructure investments, tariffs, taxes, and energy, environmental and social policies.
 Many of the risks and uncertainties identified in this Form 10-K have, and will be, exacerbated by the impacts of a catastrophic event and the actions taken by governmental entities, businesses, individuals and others in response to such an event. In addition, impacts of international conflict, recession, pandemic or similar events on SCE's customers and third parties could also result in SCE facing, among other things, significant reductions in demand for electricity and payment delays and/or defaults from customers which could result in significant under-collections. Edison International and SCE access to the bank and capital markets and/or the costs of accessing those markets could be constrained and could also face payment delays and/or defaults from insurers and other counterparties. These impacts, among others, could materially and adversely impact Edison International's and SCE's business, operations, cash flows, liquidity and financial results.
 Edison International's and SCE's business activities are concentrated in one industry and in one region.
 Substantially all of Edison International's and all of SCE's business activities are concentrated in the electric utility industry. Edison International's principal subsidiary, SCE, serves customers only in southern and central California. As a result, Edison International's and SCE's future performance may be affected by events and economic factors unique to California or by regional regulation, legislation or judicial decisions. For example, California courts have applied strict liability to investor-owned utilities in wildfire and other litigation matters. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

 QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 Information responding to this section is included in the MD&A under the heading "Market Risk Exposures."

 FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

 Report of Independent Registered Public Accounting Firm
 To the Board of Directors and Shareholders of Edison International
 Opinions on the Financial Statements and Internal Control over Financial Reporting
 We have audited the accompanying consolidated balance sheets of Edison International and its subsidiaries (the "Company") as of December 31, 2024 and 2023, and the related consolidated statements of income, of comprehensive income, of changes in equity and of cash flows for each of the three years in the period ended December 31, 2024, including the related notes and schedule of condensed financial information of parent as of December 31, 2024 and 2023 and for each of the three years in the period ended December 31, 2024 appearing under Item 15(a)(2) (collectively referred to as the "consolidated financial statements"). We also have audited the Company's internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
 In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.
 Basis for Opinions
 The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management's Report on Internal Control over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company's consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
 We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
 Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
 Definition and Limitations of Internal Control over Financial Reporting
 A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

 Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 Critical Audit Matters
 The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
 Wildfire-Related Claims - 2017/2018 Wildfire/Mudslide Events
 As described in Note 12 to the consolidated financial statements, the Thomas Fire, the Koenigstein Fire, the Montecito Mudslides and the Woolsey Fire (collectively, the "2017/2018 Wildfire/Mudslide Events") within the Company's service area caused loss of life, substantial damage to both residential and business properties, and service outages for the Company's customers. Numerous claims related to wildfire events have been initiated against the Company. The Company has incurred material losses in connection with the 2017/2018 Wildfire/Mudslide Events. As disclosed by management, management records loss contingencies when it determines that the outcome of future events is probable of occurring and when the amount of the loss can be reasonably estimated. As of December 31, 2024, the Company had paid $9.5 billion under executed settlements, had $86 million to be paid under executed settlements, including $57 million to be paid under the Safety and Enforcement Division agreement, and had $340 million of estimated losses for remaining alleged and potential claims reflected on its consolidated balance sheets related to the 2017/2018 Wildfire/Mudslide Events. As of the same date, the Company had assets for expected recoveries through Federal Energy Regulatory Commission (FERC) electric rates of $64 million on its consolidated balance sheets and had exhausted expected insurance recoveries related to the 2017/2018 Wildfire/Mudslide Events. Each reporting period, management reviews the Company's loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, and prior experience litigating and settling wildfire litigation claims. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. For the year ended December 31, 2024 management recorded charges for wildfire claims of $490 million and expected revenue from FERC customers of $27 million. The resulting pre-tax charge to earnings was $463 million ($333 million after-tax).
 The principal considerations for our determination that performing procedures relating to the wildfire-related claims from the 2017/2018 Wildfire/Mudslide Events is a critical audit matter are (i) the significant judgment by management when determining whether the outcome of future events is probable of occurring and whether the amount of the loss can be reasonably estimated as well as in estimating losses associated with alleged and potential claims related to wildfire events and (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's significant assumptions related to estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, and prior experience litigating and settling wildfire litigation claims.
 Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management's assessment of loss contingencies associated with alleged and potential claims related to wildfire events. These procedures also included, among others (i) obtaining and evaluating the letters of audit inquiry with internal and external legal counsel; (ii) assessing the reasonableness of management's assessment regarding whether the outcome of future events is probable of occurring and whether the amount of the loss can be reasonably estimated; (iii) evaluating the appropriateness of the methods used by management in estimating losses associated with alleged and potential claims related to wildfire events; (iv) evaluating the reasonableness of the significant assumptions related to estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, and prior experience litigating and settling wildfire litigation claims; and (v) testing, on a sample basis, damage claim settlements. Evaluating management's assumptions involved evaluating whether the assumptions used by management were reasonable considering (i) current damage claim settlements; (ii) past wildfire litigation history; and (iii) third-party source data.

 Accounting for the Effects of Rate Regulation
 As described in Notes 1 and 11 to the consolidated financial statements, the Company's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission (CPUC) and the FERC. Management applies authoritative guidance for rate-regulated enterprises to the portion of the Company's operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. As disclosed by management, management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to the Company or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. As of December 31, 2024, $11.6 billion was recorded in regulatory assets and $11.5 billion was recorded in regulatory liabilities.
 The principal considerations for our determination that performing procedures relating to the Company's accounting for the effects of rate regulation is a critical audit matter are a high degree of auditor effort in performing procedures and evaluating audit evidence related to (i) accounting for the effect of rate regulation on regulatory assets and liabilities and (ii) management's assessment of the recoverability and settlement of existing and new regulatory assets and liabilities.
 Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the Company's regulatory accounting process, including controls over management's assessment of the recoverability and settlement of existing and new regulatory assets and liabilities. These procedures also included, among others (i) obtaining and evaluating the Company's correspondence with regulators; (ii) evaluating management's assessment regarding the probability of recovery of regulatory assets and settlement of regulatory liabilities at the balance sheet date; (iii) evaluating the appropriateness of the accounting for the effects of the rate regulation; (iv) evaluating the sufficiency of the disclosure; and (v) testing, on a sample basis, the calculation of regulatory assets and regulatory liabilities based on provisions outlined in the rate orders.

 /s/ PricewaterhouseCoopers LLP
 Los Angeles, California
 We have served as the Company's auditor since 2002.

 Report of Independent Registered Public Accounting Firm
 To the Board of Directors and Shareholders of Southern California Edison Company
 Opinion on the Financial Statements
 We have audited the accompanying consolidated balance sheets of Southern California Edison Company and its subsidiaries (the "Company") as of December 31, 2024 and 2023, and the related consolidated statements of income, of comprehensive income, of changes in equity and of cash flows for each of the three years in the period ended December 31, 2024, including the related notes (collectively referred to as the "consolidated financial statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024 in conformity with accounting principles generally accepted in the United States of America.
 Basis for Opinion
 These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
 We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
 Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
 Critical Audit Matters
 The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
 Wildfire-Related Claims - 2017/2018 Wildfire/Mudslide Events
 As described in Note 12 to the consolidated financial statements, the Thomas Fire, the Koenigstein Fire, the Montecito Mudslides and the Woolsey Fire (collectively, the "2017/2018 Wildfire/Mudslide Events") within the Company's service area caused loss of life, substantial damage to both residential and business properties, and service outages for the Company's customers. Numerous claims related to wildfire events have been initiated against the Company. The Company has incurred material losses in connection with the 2017/2018 Wildfire/Mudslide Events. As disclosed by management, management records loss contingencies when it determines that the outcome of future events is probable of occurring and when the amount of the loss can be reasonably estimated. As of December 31, 2024, the Company had paid $9.5 billion under executed settlements, had $86 million to be paid under executed settlements, including $57 million to be paid under the Safety and Enforcement Division agreement, and had $340 million of estimated losses for remaining alleged and potential claims reflected on its consolidated balance sheets related to the 2017/2018 Wildfire/Mudslide Events. As of the same date, the Company had assets for expected recoveries through Federal Energy Regulatory Commission (FERC) electric rates of $64 million on its consolidated balance sheets and had exhausted expected insurance recoveries related to

 the 2017/2018 Wildfire/Mudslide Events. Each reporting period, management reviews the Company's loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, and prior experience litigating and settling wildfire litigation claims. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. For the year ended December 31, 2024 management recorded charges for wildfire claims of $490 million and expected revenue from FERC customers of $27 million. The resulting pre-tax charge to earnings was $463 million ($333 million after-tax).
 The principal considerations for our determination that performing procedures relating to the wildfire-related claims from the 2017/2018 Wildfire/Mudslide Events is a critical audit matter are (i) the significant judgment by management when determining whether the outcome of future events is probable of occurring and whether the amount of the loss can be reasonably estimated as well as in estimating losses associated with alleged and potential claims related to wildfire events and (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's significant assumptions related to estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, and prior experience litigating and settling wildfire litigation claims.
 Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management's assessment of loss contingencies associated with alleged and potential claims related to wildfire events. These procedures also included, among others (i) obtaining and evaluating the letters of audit inquiry with internal and external legal counsel; (ii) assessing the reasonableness of management's assessment regarding whether the outcome of future events is probable of occurring and whether the amount of the loss can be reasonably estimated; (iii) evaluating the appropriateness of the methods used by management in estimating losses associated with alleged and potential claims related to wildfire events; (iv) evaluating the reasonableness of the significant assumptions related to estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, and prior experience litigating and settling wildfire litigation claims; and (v) testing, on a sample basis, damage claim settlements. Evaluating management's assumptions involved evaluating whether the assumptions used by management were reasonable considering (i) current damage claim settlements; (ii) past wildfire litigation history; and (iii) third-party source data.
 Accounting for the Effects of Rate Regulation
 As described in Notes 1 and 11 to the consolidated financial statements, the Company's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission (CPUC) and the FERC. Management applies authoritative guidance for rate-regulated enterprises to the portion of the Company's operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. As disclosed by management, management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to the Company or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. As of December 31, 2024, $11.6 billion was recorded in regulatory assets and $11.5 billion was recorded in regulatory liabilities.
 The principal considerations for our determination that performing procedures relating to the Company's accounting for the effects of rate regulation is a critical audit matter are a high degree of auditor effort in performing procedures and evaluating audit evidence related to (i) accounting for the effect of rate regulation on regulatory assets and liabilities and (ii) management's assessment of the recoverability and settlement of existing and new regulatory assets and liabilities.
 Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the Company's regulatory accounting process, including controls over management's assessment of the recoverability and settlement of existing and new regulatory assets and liabilities. These procedures also included, among

 others (i) obtaining and evaluating the Company's correspondence with regulators; (ii) evaluating management's assessment regarding the probability of recovery of regulatory assets and settlement of regulatory liabilities at the balance sheet date; (iii) evaluating the appropriateness of the accounting for the effects of the rate regulation; (iv) evaluating the sufficiency of the disclosure; and (v) testing, on a sample basis, the calculation of regulatory assets and regulatory liabilities based on provisions outlined in the rate orders.

 /s/ PricewaterhouseCoopers LLP
 Los Angeles, California
 We have served as the Company's auditor since 2002.

 CONSOLIDATED FINANCIAL STATEMENTS

 Consolidated Statements of Income

 (in millions, except per-share amounts)
 2024
 2023
 2022

 Operating revenue
 $
 17,599
 $
 16,338
 $
 17,220

 Purchased power and fuel
 5,209
 5,486
 6,375

 Operation and maintenance
 5,172
 4,138
 4,724

 Wildfire-related claims, net of insurance recoveries
 1,313

 Wildfire Insurance Fund expense

 2,866
 2,635
 2,561

 Property and other taxes

 —

 Total operating expenses
 14,669
 13,711
 15,737

 Operating income
 2,930
 2,627
 1,483

 Interest expense
 ( 1,869)
 ( 1,612)
 ( 1,169)

 Other income, net

 Income before income taxes
 1,563
 1,515

 Income tax expense (benefit)
 ( 162)

 1,546
 1,407

 Less: Preference stock dividend requirements of SCE

 Preferred stock dividend requirements of Edison International

 Net income available to Edison International common shareholders
 1,284
 1,197

 Basic earnings per share:

 Weighted average shares of common stock outstanding

 Basic earnings per common share available to Edison International common shareholders
 $
 3.33
 $
 3.12
 $
 1.61

 Diluted earnings per share:

 Weighted average shares of common stock outstanding, including effect of dilutive securities

 Diluted earnings per common share available to Edison International common shareholders
 $
 3.31
 $
 3.11
 $
 1.60

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Comprehensive Income

 2024
 2023
 2022

 $
 1,546
 $
 1,407
 $

 Other comprehensive income (loss), net of tax:

 Pension and postretirement benefits other than pensions
 ( 1)

 Foreign currency translation adjustments
 —
 —

 Other comprehensive income, net of tax

 Comprehensive income
 1,555
 1,409

 Less: Comprehensive income attributable to noncontrolling interests

 Comprehensive income attributable to Edison International
 $
 1,380
 $
 1,286
 $

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Balance Sheets

 2024
 2023

 ASSETS

 $
 $

 Receivables, less allowances of $ 352 and $ 360 for uncollectible accounts at respective dates

 2,169
 2,016

 Accrued unbilled revenue

 Prepaid expenses

 Regulatory assets
 2,748
 2,524

 Wildfire Insurance Fund contributions

 Other current assets

 Total current assets
 7,155
 6,811

 Nuclear decommissioning trusts
 4,286
 4,173

 Other investments

 Total investments
 4,343
 4,227

 Utility property, plant and equipment, less accumulated depreciation and amortization of $ 14,207 and $ 12,910 at respective dates

 59,047
 55,877

 Nonutility property, plant and equipment, less accumulated depreciation of $ 124 and $ 114 at respective dates

 Total property, plant and equipment
 59,254
 56,084

 Receivables, less allowances of $ 43 and $ 4 for uncollectible accounts at respective dates

 Regulatory assets (include $ 1,512 and $ 1,558 related to a Variable Interest Entity "VIE" at respective dates)

 8,886
 8,897

 Wildfire Insurance Fund contributions
 1,878
 1,951

 Operating lease right-of-use assets
 1,180
 1,221

 Long-term insurance receivables

 Other long-term assets
 2,403
 2,062

 Total other assets
 14,827
 14,636

 $
 85,579
 $
 81,758

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Balance Sheets

 (in millions, except share amounts)
 2024
 2023

 LIABILITIES AND EQUITY

 Short-term debt
 $
 $
 1,077

 2,049
 2,697

 Accounts payable
 2,000
 1,983

 Accrued interest

 Regulatory liabilities
 1,347

 Current portion of operating lease liabilities

 Other current liabilities
 1,439
 1,538

 Total current liabilities
 8,439
 8,598

 Long-term debt (include $ 1,468 and $ 1,515 related to a VIE at respective dates)

 33,534
 30,316

 Deferred income taxes and credits
 7,180
 6,672

 Pensions and benefits

 Asset retirement obligations
 2,580
 2,666

 Regulatory liabilities
 10,159
 9,420

 Operating lease liabilities
 1,056
 1,101

 1,368

 Other deferred credits and other long-term liabilities
 3,566
 3,258

 Total deferred credits and other liabilities
 25,866
 24,900

 Total liabilities
 67,839
 63,814

 Commitments and contingencies (Note 12)

 Preferred stock ( 50,000,000 shares authorized; 1,159,317 shares of Series A and 503,454 and 532,454 shares of Series B issued and outstanding at respective dates)

 1,645
 1,673

 Common stock, no par value ( 800,000,000 shares authorized; 384,784,719 and 383,924,912 shares issued and outstanding at respective dates)

 6,353
 6,338

 Accumulated other comprehensive loss
 —
 ( 9)

 Retained earnings
 7,567
 7,499

 Total Edison International's shareholders' equity
 15,565
 15,501

 Noncontrolling interests – preference stock of SCE
 2,175
 2,443

 Total equity
 17,740
 17,944

 Total liabilities and equity
 $
 85,579
 $
 81,758

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Cash Flows

 2024
 2023
 2022

 Cash flows from operating activities:

 $
 1,546
 $
 1,407
 $

 Adjustments to reconcile to net cash provided by operating activities:

 2,939
 2,721
 2,633

 Allowance for equity during construction
 ( 187)
 ( 157)
 ( 137)

 —

 ( 177)

 Wildfire Insurance Fund amortization expense

 Other

 Nuclear decommissioning trusts
 ( 180)

 Contributions to Wildfire Insurance Fund
 ( 95)
 ( 95)
 ( 95)

 Changes in operating assets and liabilities:

 Receivables
 ( 278)
 ( 349)
 ( 252)

 ( 14)
 ( 63)
 ( 58)

 Accounts payable
 ( 408)

 Tax receivables and payables
 ( 43)

 Other current assets and liabilities
 ( 42)

 Derivative assets and liabilities, net

 Regulatory assets and liabilities, net
 1,219
 ( 51)

 Wildfire-related insurance receivable
 ( 36)
 ( 390)

 ( 397)
 ( 410)
 ( 56)

 Other noncurrent assets and liabilities
 ( 4)

 5,014
 3,401
 3,216

 Cash flows from financing activities:

 Long-term debt issued, net of discount and issuance costs of $ 44, $ 54, and $ 62 for the respective years

 5,256
 5,121
 5,971

 Long-term debt repaid
 ( 2,701)
 ( 2,498)
 ( 1,085)

 Short-term debt issued
 —
 1,076
 1,000

 Short-term debt repaid
 ( 401)
 ( 2,407)
 ( 1,543)

 Common stock repurchased
 —
 —

 Preferred and preference stock issued, net of issuance cost
 —

 Preferred and preference stock repurchased and redeemed
 ( 656)
 ( 289)
 —

 Commercial paper borrowing (repayments), net
 1,102
 ( 317)

 Dividends and distribution to noncontrolling interests
 ( 168)
 ( 117)
 ( 110)

 Common stock dividends paid
 ( 1,198)
 ( 1,112)
 ( 1,050)

 Preferred stock dividends paid
 ( 88)
 ( 99)

 Other

 1,447
 2,881

 Cash flows from investing activities:

 Capital expenditures
 ( 5,707)
 ( 5,448)
 ( 5,778)

 Proceeds from sale of nuclear decommissioning trust investments
 5,019
 4,597
 4,177

 Purchases of nuclear decommissioning trust investments
 ( 4,898)
 ( 4,417)
 ( 4,054)

 Other

 Net cash used in investing activities
 ( 5,536)
 ( 5,233)
 ( 5,574)

 Net increase (decrease) in cash, cash equivalents and restricted cash
 ( 385)

 Cash, cash equivalents and restricted cash at beginning of year

 Cash, cash equivalents and restricted cash at end of year
 $
 $
 $

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Changes in Equity

 Equity Attributable to Edison International Shareholders
 Noncontrolling
Interests

 (in millions, except per share amounts)
 Preferred
Stock
 Common
Stock
 Accumulated
Other
Comprehensive
Loss
 Retained
Earnings
 Subtotal
 Preference
Stock
 Total
Equity

 Balance at December 31, 2021
 $
 1,977
 $
 6,071
 $
 ( 54)
 $
 7,894
 $
 15,888
 $
 1,901
 $
 17,789

 —
 —
 —

 —
 —
 —
 —

 Common stock issued
 —
 —
 —
 —

 Common stock dividends declared ($ 2.8375 per share)

 —
 —
 —
 ( 1,083)
 ( 1,083)
 —
 ( 1,083)

 Preferred stock dividend accrued ($ 53.75 per share for Series A and $ 42.08333 per share for Series B)

 —
 —
 —
 ( 74)
 ( 74)
 —
 ( 74)

 Dividends to noncontrolling interests ($ 65.1098 - $ 143.75 per share for preference stock)

 —
 —
 —
 —
 —

 —
 —
 —
 —

 Other
 —
 —
 —
 —

 Balance at December 31, 2022
 1,978
 6,200
 ( 11)
 7,454
 15,621
 1,901
 17,522

 —
 —
 —
 1,284
 1,284
 1,407

 —
 —
 —
 —

 Common stock issued
 —
 —
 —
 —

 Common stock dividends declared ($ 2.9925 per share)

 —
 —
 —
 ( 1,147)
 ( 1,147)
 —
 ( 1,147)

 Preferred stock dividend declared ($ 53.75 per share for Series A and $ 50.00 per share for Series B)

 —
 —
 —
 —

 Dividends to noncontrolling interests ($ 96.823 - $ 143.75 per share for preference stock)

 —
 —
 —
 —
 —

 —
 —
 —
 —

 Preference stock issued, net of issuance cost
 —
 —
 —
 —
 —

 Preferred stock repurchased
 ( 305)
 —
 —
 ( 289)
 —
 ( 289)

 Balance at December 31, 2023
 1,673
 6,338
 ( 9)
 7,499
 15,501
 2,443
 17,944

 —
 —
 —
 1,371
 1,371
 1,546

 —
 —
 —
 —

 Common stock issued
 —
 —
 —
 —

 Common stock repurchased
 —
 —
 —
 —

 Common stock dividends declared ($ 3.1675 per share)

 —
 —
 —
 ( 1,221)
 ( 1,221)
 —
 ( 1,221)

 Preferred stock dividend declared ($ 53.75 per share for Series A and $ 50.00 per share for Series B)

 —
 —
 —
 ( 88)
 ( 88)
 —
 ( 88)

 Dividends to noncontrolling interests ($ 24.418 - $ 199.479 per share for preference stock)

 —
 —
 —
 ( 160)
 ( 154)

 —
 —
 —
 —

 Preference stock issued, net of issuance cost
 —
 —
 —
 —
 —

 Preference stock redeemed
 —
 —
 —
 —
 —
 ( 628)
 ( 628)

 Preferred stock repurchased
 ( 28)
 —
 —
 —
 ( 28)
 —
 ( 28)

 Balance at December 31, 2024
 $
 1,645
 $
 6,353
 $
 —
 $
 7,567
 $
 15,565
 $
 2,175
 $
 17,740

 The accompanying notes are an integral part of these consolidated financial statements.

 (This page has been left blank intentionally.)

 Consolidated Statements of Income

 2024
 2023
 2022

 Operating revenue
 $
 17,547
 $
 16,275
 $
 17,172

 Purchased power and fuel
 5,209
 5,486
 6,375

 Operation and maintenance
 5,064
 4,071
 4,659

 Wildfire-related claims, net of insurance recoveries
 1,305

 Wildfire Insurance Fund expense

 2,865
 2,633
 2,559

 Property and other taxes

 —

 Total operating expenses
 14,551
 13,635
 15,659

 Operating income
 2,996
 2,640
 1,513

 Interest expense
 ( 1,575)
 ( 1,356)
 ( 1,005)

 Other income, net

 Income before income taxes
 1,914
 1,781

 Income tax expense (benefit)
 ( 109)

 1,794
 1,597

 Less: Preference stock dividend requirements

 Net income available for common stock
 $
 1,619
 $
 1,474
 $

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Comprehensive Income

 2024
 2023
 2022

 $
 1,794
 $
 1,597
 $

 Other comprehensive income (loss), net of tax:

 Pension and postretirement benefits other than pensions
 ( 4)

 Other comprehensive income (loss), net of tax
 ( 4)

 Comprehensive income
 $
 1,797
 $
 1,593
 $

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Balance Sheets

 2024
 2023

 ASSETS

 $
 $

 Receivables, less allowances of $ 347 and $ 360 for uncollectible accounts at respective dates

 2,160
 1,981

 Accrued unbilled revenue

 Prepaid expenses

 Regulatory assets
 2,748
 2,524

 Wildfire Insurance Fund contributions

 Other current assets

 Total current assets
 7,024
 6,633

 Nuclear decommissioning trusts
 4,286
 4,173

 Other investments

 Total investments
 4,324
 4,211

 Utility property, plant and equipment, less accumulated depreciation and amortization of $ 14,207 and $ 12,910 at respective dates

 59,047
 55,877

 Nonutility property, plant and equipment, less accumulated depreciation of $ 108 and $ 100 at respective dates

 Total property, plant and equipment
 59,246
 56,078

 Receivables, less allowances of $ 43 and $ 4 for uncollectible accounts at respective dates

 Regulatory assets (include $ 1,512 and $ 1,558 related to a VIE at respective dates)

 8,886
 8,897

 Wildfire Insurance Fund contributions
 1,878
 1,951

 Operating lease right-of-use assets
 1,174
 1,214

 Long-term insurance receivables

 Long-term insurance receivables due from affiliate

 Other long-term assets
 2,317
 1,983

 Total other assets
 14,751
 14,561

 $
 85,345
 $
 81,483

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Balance Sheets

 (in millions, except share amounts)
 2024
 2023

 LIABILITIES AND EQUITY

 Short-term debt
 $
 $

 1,249
 2,197

 Accounts payable
 2,078
 1,966

 Accrued interest

 Regulatory liabilities
 1,347

 Current portion of operating lease liabilities

 Other current liabilities
 1,495
 1,535

 Total current liabilities
 7,290
 7,795

 Long-term debt (include $ 1,468 and $ 1,515 related to a VIE at respective dates)

 29,266
 26,297

 Deferred income taxes and credits
 8,697
 8,126

 Pensions and benefits

 Asset retirement obligations
 2,580
 2,666

 Regulatory liabilities
 10,159
 9,420

 Operating lease liabilities
 1,051
 1,096

 1,368

 Other deferred credits and other long-term liabilities
 3,518
 3,206

 Total deferred credits and other liabilities
 27,038
 25,987

 Total liabilities
 63,594
 60,079

 Commitments and contingencies (Note 12)

 Preference stock
 2,220
 2,495

 Common stock, no par value ( 560,000,000 shares authorized; 434,888,104 shares issued and outstanding at respective dates)

 2,168
 2,168

 Additional paid-in capital
 8,950
 8,446

 Accumulated other comprehensive loss
 ( 9)
 ( 12)

 Retained earnings
 8,422
 8,307

 Total equity
 21,751
 21,404

 Total liabilities and equity
 $
 85,345
 $
 81,483

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Cash Flows

 2024
 2023
 2022

 Cash flows from operating activities:

 $
 1,794
 $
 1,597
 $

 Adjustments to reconcile to net cash provided by operating activities:

 2,929
 2,710
 2,626

 Allowance for equity during construction
 ( 187)
 ( 157)
 ( 137)

 —

 ( 111)

 Wildfire Insurance Fund amortization expense

 Other

 Nuclear decommissioning trusts
 ( 180)

 Contributions to Wildfire Insurance Fund
 ( 95)
 ( 95)
 ( 95)

 Changes in operating assets and liabilities:

 Receivables
 ( 298)
 ( 336)
 ( 245)

 ( 14)
 ( 63)
 ( 58)

 Accounts payable
 ( 413)

 Tax receivables and payables
 ( 44)
 ( 1)

 Other current assets and liabilities
 ( 41)

 Derivative assets and liabilities, net

 Regulatory assets and liabilities, net
 1,219
 ( 51)

 Wildfire-related insurance receivable
 ( 39)
 ( 398)

 ( 397)
 ( 410)
 ( 56)

 Other noncurrent assets and liabilities

 5,383
 3,681
 3,319

 Cash flows from financing activities:

 Long-term debt issued, net of discount and issuance costs of $ 36, $ 37 and $ 51 for the respective years

 4,214
 3,588
 5,032

 Long-term debt repaid
 ( 2,201)
 ( 2,098)
 ( 385)

 Short-term debt borrowed
 —
 —

 Short-term debt repaid
 ( 386)
 ( 1,051)
 ( 1,543)

 Capital contributions from Edison International Parent
 —
 1,400

 Preference stock issued, net of issuance cost
 —

 Preference stock redeemed
 ( 628)
 —
 —

 Commercial paper borrowing (repayments), net
 ( 406)

 Common stock dividends paid
 ( 1,440)
 ( 1,400)
 ( 1,300)

 Preference stock dividends paid
 ( 168)
 ( 117)
 ( 110)

 Other
 ( 16)

 1,182
 2,724

 Cash flows from investing activities:

 Capital expenditures
 ( 5,703)
 ( 5,446)
 ( 5,776)

 Proceeds from sale of nuclear decommissioning trust investments
 5,019
 4,597
 4,177

 Purchases of nuclear decommissioning trust investments
 ( 4,898)
 ( 4,417)
 ( 4,054)

 Other

 Net cash used in investing activities
 ( 5,530)
 ( 5,231)
 ( 5,557)

 Net increase (decrease) in cash and cash equivalents
 ( 368)

 Cash, cash equivalents and restricted cash at beginning of year

 Cash, cash equivalents and restricted cash at end of year
 $
 $
 $

 The accompanying notes are an integral part of these consolidated financial statements.

 Consolidated Statements of Changes in Equity

 (in millions, except per share amounts)
 Preference
Stock
 Common
Stock
 Additional
Paid-in
Capital
 Accumulated
Other
Comprehensive
Loss
 Retained
Earnings
 Total
Equity

 Balance at December 31, 2021
 $
 1,945
 $
 2,168
 $
 7,033
 $
 ( 32)
 $
 8,721
 $
 19,835

 —
 —
 —
 —

 —
 —
 —
 —

 Capital contribution from Edison International Parent
 —
 —
 1,400
 —
 —
 1,400

 Dividends declared on common stock ($ 3.0468 per share)

 —
 —
 —
 —
 ( 1,325)
 ( 1,325)

 Dividends declared on preference stock ($ 65.1098 - $ 143.75 per share)

 —
 —
 —
 —

 Stock-based compensation
 —
 —
 ( 14)
 —
 —
 ( 14)

 —
 —
 —
 —

 Balance at December 31, 2022
 $
 1,945
 $
 2,168
 $
 8,441
 $
 ( 8)
 $
 8,243
 $
 20,789

 —
 —
 —
 —
 1,597
 1,597

 —
 —
 —
 ( 4)
 —
 ( 4)

 Dividends declared on common stock ($ 3.2422 per share)

 —
 —
 —
 —
 ( 1,410)
 ( 1,410)

 Dividends declared on preference stock ($ 96.823 - $ 143.75 per share)

 —
 —
 —
 —

 Stock-based compensation
 —
 —
 ( 13)
 —
 —
 ( 13)

 —
 —
 —
 —

 Preference stock issued
 —
 ( 8)
 —
 —

 Balance at December 31, 2023
 $
 2,495
 $
 2,168
 $
 8,446
 $
 ( 12)
 $
 8,307
 $
 21,404

 —
 —
 —
 —
 1,794
 1,794

 —
 —
 —
 —

 Capital contribution from Edison International Parent
 —
 —
 —
 —

 Dividends declared on common stock ($ 3.4722 per share)

 —
 —
 —
 —
 ( 1,510)
 ( 1,510)

 Dividends declared on preference stock ($ 24.418 - $ 199.479 per share)

 —
 —
 —
 —
 ( 154)
 ( 154)

 Stock-based compensation
 —
 —
 ( 35)
 —
 —
 ( 35)

 —
 —
 —
 —

 Preference stock issued
 —
 ( 5)
 —
 —

 Preference stock redeemed
 ( 625)
 —
 —
 ( 15)
 ( 628)

 Balance at December 31, 2024
 $
 2,220
 $
 2,168
 $
 8,950
 $
 ( 9)
 $
 8,422
 $
 21,751

 The accompanying notes are an integral part of these consolidated financial statements.

 NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 Note 1. Summary of Significant Accounting Policies
 Organization and Basis of Presentation
 Edison International is the ultimate parent holding company of SCE and Edison Energy, LLC, doing business as Trio. SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area across Southern, Central, and Coastal California. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial, and institutional customers. Trio's business activities are currently not material to report as a separate business segment, and SCE is the single reportable segment. See "Segment Information" below for further discussion.
 These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE, and other controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to "Edison International Parent and Other" refer to Edison International Parent and its competitive subsidiaries and "Edison International Parent" refer to Edison International on a stand-alone basis, not consolidated with its subsidiaries. SCE's consolidated financial statements include the accounts of SCE, its controlled subsidiaries and a variable interest entity, SCE Recovery Funding LLC., of which SCE is the primary beneficiary. All intercompany transactions have been eliminated from the consolidated financial statements.
 Edison International's and SCE's accounting policies conform to GAAP, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the CPUC and the FERC. SCE applies authoritative guidance for rate-regulated enterprises to the portion of its operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. In addition, SCE recognizes revenue and regulatory assets from alternative revenue programs, which enables the utility to adjust future rates in response to past activities or completed events, if certain criteria are met. SCE assesses at the end of each reporting period whether regulatory assets are probable of future recovery. See Note 11 for the composition of regulatory assets and liabilities.
 The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates. Certain prior period amounts have been conformed to the current period's presentation, including the separate presentation of accrued interest on Edison International's and SCE's consolidated balance sheets.
 Segment Information
 The President and Chief Executive Officer ("CEO") of Edison International, as the chief operating decision maker ("CODM"), assesses Edison International's performance and allocates resources based on its net income. This measure is reported as "Net income attributable to Edison International common shareholders" on Edison International's consolidated statements of income. The President and CEO of SCE, as its CODM, evaluates SCE's performance and allocates resources based on "Net income available for common stock" reported on SCE's consolidated statements of income. These net income measures are used by the Edison International and SCE CODMs to compare earnings from period to period and facilitate their respective assessment of performance of Edison International and SCE. The CODMs also use core earnings (loss) for financial planning and for additional analyses of performance. Core earnings (loss) is a non-GAAP financial measure which is defined as earnings attributable to shareholders less non-core items. Non-core items include income or loss from discontinued operations and income or loss from significant discrete items that management does not consider representative of ongoing earnings. Edison International's and SCE's significant segment expenses agree to those disclosed in the consolidated statements of income. The measures of Edison International's and SCE's segment assets are reported on Edison International's and SCE's consolidated balance sheets, respectively, as total assets.

 Cash, Cash Equivalents and Restricted Cash
 Cash equivalents consist of investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less. The cash equivalents were as follows:

 SCE

 2024
 2023
 2024
 2023

 Money market funds
 $
 $
 $
 —
 $

 Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period.
 The following table sets forth the cash, cash equivalents and restricted cash included in the consolidated statements of cash flows:

 2024
 2023

 $
 $

 Short-term restricted cash1

 Long-term restricted cash2

 Total cash, cash equivalents and restricted cash
 $
 $

 SCE:

 $
 $

 Short-term restricted cash1

 Long-term restricted cash2

 Total cash, cash equivalents and restricted cash
 $
 $

 1Includes SCE Recovery Funding LLC's restricted cash for payments of senior secured recovery bonds and is reflected in "Other current assets" on Edison International's and SCE's consolidated balance sheets.
 2The SCE amount represents cash collected for customer-funded wildfire self-insurance and is reflected in "Other long-term assets" on Edison International's and SCE's consolidated balance sheets. See Note 12 for further information.
 Allowance for Uncollectible Accounts
 The allowance for uncollectible accounts is recorded based on SCE's estimate of expected credit losses and adjusted over the life of the receivables as needed. Since the customer base of SCE is concentrated in Southern California which exposes SCE to a homogeneous set of economic conditions, the allowance is measured on a collective basis on the historical amounts written-off, assessment of customer collectibility and current economic trends, including unemployment rates and any likelihood of recession for the region. The increase in the provision of uncollectible accounts and write-offs for the year ended December 31, 2024, is driven primarily by consumer protection programs.

 The following table sets forth the changes in allowance for uncollectible accounts for SCE:

 Customers
 All others
 Total

 Balance at December 31, 2021
 $
 $
 $

 Current period provision for uncollectible accounts1

 Write-offs, net of recoveries
 ( 70)
 ( 7)
 ( 77)

 Balance at December 31, 2022
 $
 $
 $

 Current period provision for uncollectible accounts1

 Write-offs, net of recoveries
 ( 96)
 ( 9)
 ( 105)

 Balance at December 31, 2023
 $
 $
 $

 Current period provision for uncollectible accounts1

 Write-offs, net of recoveries
 ( 253)
 ( 11)
 ( 264)

 Balance at December 31, 2024
 $
 $
 $

 1This includes $ 222 million, $ 78 million, and $ 40 million of incremental costs for the years ended December 31, 2024, 2023, and 2022, respectively, which were probable of recovery from customers and recorded as regulatory assets.
 2Approximately $ 43 million and $ 4 million of allowance for uncollectible accounts are included in "Other long-term assets" on SCE's consolidated balance sheets as of December 31, 2024 and 2023 respectively.
 SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at weighted average cost or net realizable value when appropriate.
 Emission Allowances and Energy Credits
 SCE is allocated GHG allowances annually which it is then required to sell into quarterly auctions. GHG proceeds from the auctions are recorded as a regulatory liability to be refunded to customers. SCE purchases GHG allowances in quarterly auctions or from counterparties to satisfy its GHG emission compliance obligations and recovers such costs of GHG allowances from customers. GHG allowances held for use are classified as "Other current assets" on the consolidated balance sheets and are stated, similar to an inventory method, at the lower of weighted average cost or market. SCE will evaluate GHG allowances for impairment upon a triggering event that would indicate SCE might not recover the full cost of an allowance. SCE had GHG allowances held for use of $ 66 million and $ 128 million at December 31, 2024 and 2023, respectively. GHG emission obligations were $ 22 million and $ 117 million at December 31, 2024 and 2023, respectively, and are classified as "Other current liabilities" on the consolidated balance sheets.
 SCE is allocated low carbon fuel standard ("LCFS") credits which it sells to market participants. Proceeds from the sales, net of selling fees and program administration expenses, are recorded in a balancing account to be refunded to eligible customers. SCE's net proceeds from the sale of these LCFS credits were $ 243 million and $ 248 million at December 31, 2024 and 2023, respectively. LCFS credits are classified as "Regulatory liabilities" on the consolidated balance sheets.
 Property, Plant and Equipment
 SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, employee benefits, and property taxes are capitalized as part of plant additions. The CPUC authorizes a capitalization rate for each of the indirect costs which are allocated to each project based on either labor or total costs.
 Estimated useful lives authorized by the CPUC in the 2021 GRC and weighted average useful lives of SCE's property, plant and equipment, are as follows:

 Estimated Useful Lives
Useful Lives

 Generation plant
 10 years to 54 years

 39 years

 Distribution plant
 20 years to 67 years

 50 years

 Transmission plant
 30 years to 65 years

 53 years

 General plant and other
 5 years to 60 years

 19 years

 Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. SCE's depreciation expense was $ 2.8 billion, $ 2.5 billion and $ 2.5 billion for 2024, 2023 and 2022, respectively. Depreciation expense stated as a percentage of average original cost of depreciable utility plant was, on a composite basis, 4.3 %, 4.1 % and 4.2 % for 2024, 2023 and 2022, respectively. The original costs of retired property are charged to accumulated depreciation. See Note 2 for further information.
 Nuclear fuel for Palo Verde is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. Palo Verde nuclear fuel is amortized using the units of production method.
 Allowance for funds used during construction ("AFUDC") represents the estimated cost of debt and equity funds that finance utility-plant construction and is capitalized during certain plant construction. AFUDC is recovered in rates through depreciation expense over the useful life of the related asset. Equity AFUDC represents a method to compensate SCE for the estimated cost of equity used to finance utility plant additions and is recorded as part of construction in progress.
 The following table summarizes SCE's AFUDC related to debt and equity:

 2024
 2023
 2022

 Debt AFUDC1

 $
 $
 $

 Equity AFUDC2

 1Reflected as a reduction of "Interest expense" on the consolidated statements of income.
 2Reflected in "Other income" on the consolidated statements of income.
 Major Maintenance
 Major maintenance costs for SCE's facilities and equipment are expensed as incurred.
 Impairment of Long-Lived Assets
 Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair value is determined via market, cost and income-based valuation techniques, as appropriate.
 Accounting principles for rate-regulated enterprises also require recognition of an impairment loss if it becomes probable that the regulated utility will abandon a plant investment, or if it becomes probable that the cost of a recently completed plant will be disallowed, either directly or indirectly, for ratemaking purposes, and a reasonable estimate of the disallowance amount can be made.
 Upon approval of the TKM Settlement Agreement, SCE will record an impairment charge of approximately $ 10 million in the first quarter of 2025. For further information on the TKM Settlement Agreement, see "Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
 Initial and annual contributions to the wildfire insurance fund established pursuant to California Assembly Bill 1054 (the "Wildfire Insurance Fund" and "AB 1054")
 Edison International and SCE accounted for the contributions to the Wildfire Insurance Fund similarly to prepaid insurance. No period of coverage was provided in AB 1054, therefore expense is being allocated to periods ratably based on an estimated period of coverage. At December 31, 2024 and 2023, Edison International and SCE had a $ 1.9 billion and a $ 2.0 billion long-term asset, respectively, as well as a $ 138 million and $ 204 million current asset, respectively, reflected as "Wildfire Insurance Fund contributions" in their consolidated balance sheets for the initial $ 2.4 billion contribution made during 2019 and the present value of annual contributions SCE committed to make to the Wildfire Insurance Fund, reduced by amortization. At December 31, 2024 and 2023, long-term liabilities of $ 363 million and $ 450 million, respectively, have been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contributions. Contributions were discounted to the present value using US treasury interest rates at the date SCE committed to participate in the Wildfire Insurance Fund.
 Edison International and SCE reassesses the period of coverage of the fund at least annually in the first quarter each year, and adjustments are applied on a prospective basis. At December 31, 2024, 2023 and 2022, the asset was amortized based on an estimated period of coverage of 20 years, 15 years, and 15 years, respectively. All expenses related to the

 contributions are being reflected in "Wildfire Insurance Fund Expense" in the consolidated statements of income. Changes in the estimated period of coverage provided by the Wildfire Insurance Fund could lead to material changes in future expense recognition. In estimating the period of coverage, Edison International and SCE used Monte Carlo simulations based on historical data from wildfires caused by electrical utility equipment to estimate expected losses, using ten years (2014 – 2023) of available historical data in 2024, nine years (2014 – 2022) of available historical data in 2023, and eight years (2014 – 2021) of available historical data in 2022. The details of the operation of the Wildfire Insurance Fund and estimates related to claims by SCE, PG&E, and SDG&E against the fund have been applied to the expected loss simulations to estimate the period of coverage of the fund. The most sensitive inputs to the estimated period of coverage are the expected frequency of wildfire events caused by investor-owned utility electrical equipment and the estimated costs associated with those forecasted events. These inputs are most affected by the historical data used in estimating expected losses. There were fires in the service area of SCE, PG&E and SDG&E since the inception of the Wildfire Insurance Fund, including fires for which the cause is unknown, which may in the future be determined to be covered by the Wildfire Insurance Fund and have not been reflected or estimated in this analysis will be included in this analysis at that time.
 As of the date of this filing, SCE is continuing to perform its annual assessment for 2025 to reassess its estimate of the life of the Wildfire Insurance Fund. Edison International and SCE assess the Wildfire Insurance Fund contribution assets for impairment each reporting period. An impairment will be recorded if the recorded asset exceeds SCE's ability to benefit from the remaining coverage provided by the Wildfire Insurance Fund.
 Nuclear Decommissioning and Asset Retirement Obligations
 The fair value of a liability for an ARO is recorded in the period in which it is incurred, including a liability for the fair value of a conditional ARO, if the fair value can be reasonably estimated even though uncertainty exists about the timing and/or method of settlement. When an ARO liability is initially recorded, SCE capitalizes the cost by increasing the carrying amount of the related long-lived asset. For each subsequent period, the liability is increased for accretion expense and the capitalized cost is depreciated over the useful life of the related asset.
 SCE has not recorded an ARO for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities.
 The following table summarizes the changes in SCE's ARO liability:

 2024
 2023

 Beginning balance
 $
 2,666
 $
 2,754

 Accretion1

 Revisions
 ( 2)
 ( 3)

 Liabilities settled
 ( 221)
 ( 229)

 Ending balance
 $
 2,580
 $
 2,666

 1An ARO represents the present value of a future obligation. Accretion is an increase in the liability to account for the time value of money resulting from discounting.
 AROs related to decommissioning of SCE's nuclear power facilities are based on site-specific studies conducted as part of each NDCTP conducted before the CPUC. ARO are revised when updated site-specific decommissioning cost estimates are available.
 The ARO for decommissioning SCE's San Onofre and Palo Verde nuclear power facilities was $ 2.1 billion as of December 31, 2024. The liability to decommission SCE's nuclear power facilities is based on a 2024 decommissioning study, filed as part of the 2024 NDCTP, for San Onofre Unit 1, 2, and 3 and a 2023 decommissioning study for Palo Verde.
 Decommissioning of San Onofre Unit 1 began in 1999 and the transfer of spent nuclear fuel from Unit 1 to dry cask storage in the Independent Spent Fuel Storage Installation ("ISFSI") 1 was completed in 2005. Major decommissioning work for Unit 1 has been completed except for certain underground work.
 Decommissioning of San Onofre Units 2 and 3 began in June 2013 and the transfer of spent nuclear fuel from San Onofre Units 2 and 3 to dry cask storage in the two ISFSIs was completed in August 2020. In August 2020, SCE commenced, and is currently conducting major decommissioning activities in accordance with the terms of the Coastal Developmental Permit for San Onofre Units 2 and 3.

 Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. Through the ratemaking process, SCE has substantially collected in rates, as a component of depreciation expense, all amounts for the future decommissioning of its nuclear assets and has placed those amounts in independent trusts. Amounts collected in rates in excess of the ARO liability are classified as ARO regulatory liabilities. See Note 11 for further information. Amortization of the ARO asset (included within the unamortized nuclear investment) and accretion of the ARO liability are deferred as decreases to the ARO regulatory liability account, resulting in no impact on earnings.
 Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $ 7.6 billion through 2098 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 2.1 % to 7.5 % (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 3.6 % to 5.7 % dependent on asset class. If the estimated costs increase, the assumed return on trust assets is not earned, or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates, subject to a reasonableness review. See Note 10 for further information.
 SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceedings. SCE's nuclear decommissioning trust investments primarily consist of fixed income investments that are classified as available-for-sale and equity investments. Due to regulatory mechanisms, investment earnings and realized gains and losses have no impact on earnings. Unrealized gains and losses on decommissioning trust funds, including impairment, increase or decrease the trust assets and the related regulatory asset or liability and have no impact on electric utility revenue or decommissioning expense. SCE reviews each fixed income security for impairment on the last day of each month. If the fair value on the last day of the month is less than the amortized cost for that security, SCE impairs the disclosed amortized cost. If the fair value is greater or less than the carrying value for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively.
 Deferred Financing Costs
 Debt premium, discount, and issuance expenses incurred in connection with obtaining financing are deferred and amortized over the life of each debt issue. These deferred amounts are recorded as an offset to long-term debt. See Note 5 for further details. Under CPUC ratemaking procedures, SCE's debt reacquisition expenses are amortized over the remaining life of the reacquired debt, or if refinanced, the life of the new debt. The unamortized losses on reacquired debt are reflected as long-term "Regulatory assets" in the consolidated balance sheets. See Note 11 for further details.
 Amortization of deferred financing costs charged to interest expense is as follows:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Amortization of deferred financing costs charged to interest expense
 $
 $
 $
 $
 $
 $

 Revenue Recognition
 Revenue is recognized by Edison International and SCE when a performance obligation to transfer control of the promised goods is satisfied or when services are rendered to customers. This typically occurs when electricity is delivered to customers, which includes amounts for services rendered but unbilled at the end of a reporting period.
 SCE's Revenue from Contracts with Customers
 Provision of Electricity
 SCE principally generates revenue through supplying and delivering electricity to its customers. Rates charged to customers are based on tariff rates, approved by the CPUC and FERC. Starting with SCE's 2021 GRC, revenue is authorized through quadrennial GRC proceedings, which are intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its CPUC-jurisdictional rate base. The CPUC sets an annual revenue requirement for the base year and the remaining three years are set by a methodology established in the GRC proceeding. As described above, SCE also earns revenue, with no return, to recover costs for power procurement, certain wildfire related expenses and other activities.

 Revenue is authorized by the FERC through a formula rate which is intended to provide SCE a reasonable opportunity to recover transmission capital and operating costs that are prudently incurred, including a return on its FERC-jurisdictional rate base. Under the operation of the formula rate, transmission revenue is updated to actual cost of service annually.
 For SCE's electricity sales for both residential and non-residential customers, SCE satisfies the performance obligation of delivering electricity over time as the customers simultaneously receive and consume the delivered electricity.
 Energy sales are typically on a month-to-month implied contract for transmission, distribution and generation services. Revenue is recognized over time as the energy is supplied and delivered to customers and the respective revenue is billed and paid on a monthly basis.
 CPUC and FERC rates decouple authorized revenue from the volume of electricity sales and the price of energy procured so that SCE has the opportunity to receive revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold does not have a direct impact on SCE's financial results. See Note 7 for further information on SCE's revenue.
 Sales and Use Taxes
 SCE bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which SCE pays to various municipalities (based on contracts with these municipalities) in order to operate within the limits of the municipality. SCE bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SCE's ability to collect from the customer, are accounted for on a gross basis. SCE's franchise fees billed to customers were $ 183 million, $ 168 million, and $ 172 million for the years ended December 31, 2024, 2023, and 2022, respectively. When SCE acts as an agent for sales and use tax, the taxes are accounted for on a net basis. Amounts billed to and collected from customers for these taxes are remitted to the taxing authorities and are not recognized as electric utility revenue.
 SCE's Alternative Revenue Programs
 The CPUC and FERC have authorized additional, alternative revenue programs which adjust billings for the effects of broad external factors or provide for additional billings if the utility achieves certain objectives. These alternative revenue programs allow SCE to recover costs that SCE has been authorized to pass on to customers, including costs of certain capital and operations and maintenance activities, costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs, and earn a reasonable return. In general, revenue is recognized for these alternative revenue programs at the time the costs are incurred, or at the time when specific events permitting billing of the additional revenues have been completed. SCE begins recognizing revenues for these programs when a program has been established by an order from either the CPUC or FERC that allows for automatic adjustment of future rates, the amount of revenue for the period is objectively determinable and probable of recovery and the revenue will be collected within 24 months following the end of the annual period.
 Power Purchase Agreements
 SCE enters into power purchase agreements ("PPAs") in the normal course of business. A power purchase agreement may be considered a variable interest in a variable interest entity ("VIE"). If SCE is the primary beneficiary in the VIE, SCE is required to consolidate the VIE. None of SCE's PPAs resulted in consolidation at December 31, 2024 and 2023. See Note 3 for further discussion of PPAs that are considered variable interests.
 A PPA may also contain a lease for accounting purposes. See "Leases" below and Note 12 and Note 13 for further discussion of SCE's PPAs. A PPA that does not contain a lease may be classified as a derivative which is recorded at fair value on the consolidated balance sheets, unless the PPA is eligible for an election to designate as a normal purchase or sale, which is accounted for on an accrual basis as an executory contract.
 PPAs that do not meet the above classifications are accounted for on an accrual basis.
 Derivative Instruments
 SCE records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value unless otherwise exempted from derivative treatment as normal purchases or sales. The normal purchases and sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business.
 Realized gains and losses from SCE's derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, therefore, SCE's fair value changes have no impact on purchased power expense or earnings. SCE does not use hedge accounting for derivative transactions due to regulatory accounting treatment.

 Where SCE's derivative instruments are subject to a master netting agreement and certain criteria are met, SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets. In addition, derivative positions are offset against margin and cash collateral deposits. The results of derivative activities are recorded as part of cash flows from operating activities on the consolidated statements of cash flows. See Note 6 for further information on derivative instruments.
 Leases
 A lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. An entity controls the use when it has a right to obtain substantially all of the benefits from the use of the asset and has the right to direct the use. SCE determines if an arrangement is a lease at contract inception. For all classes of underlying assets, except battery storage assets where each component is separately accounted for, SCE accounts for lease and non-lease components as a single lease component. Lease liabilities are recognized based on the present value of the lease payments over the lease term at the commencement date. SCE calculates and uses the rate implicit in the lease if the information is readily available or if not available, SCE uses its incremental borrowing rate in determining the present value of lease payments. Incremental borrowing rates are comprised of underlying risk-free rates and secured credit spreads relative to first mortgage bonds with like tenors of lease term durations. Lease right-of-use ("ROU") assets are based on the liability, subject to adjustments, such as lease incentives. The ROU assets also include any lease payments made at or before the commencement date. SCE excludes variable lease payments in measuring lease assets and lease liabilities. SCE's lease terms include options to extend or terminate the lease when it is reasonably certain that such options will be exercised. SCE elected to exclude from the balance sheet short-term leases of one year or less.
 SCE enters into power purchase agreements that may contain leases. This occurs when a power purchase agreement designates a specific power plant, SCE obtains substantially all of the economic benefits from the use of the plant and has the right to direct the use of the plant. SCE also enters into a number of agreements to lease property and equipment in the normal course of business, primarily related to vehicles, office space and other equipment. See Note 13 for further information on leases.
 Edison International Parent and Other's leases primarily relate to Trio, which are immaterial to Edison International.
 Stock-Based Compensation
 Stock options, performance shares, deferred stock units, and restricted stock units have been granted under Edison International's long-term incentive compensation programs. For equity awards that are settled in common stock, Edison International either issues new common stock, or uses a third party to purchase shares from the market and deliver such shares for the settlement of the awards. Stock options, performance shares, deferred stock units and restricted stock units are settled in common stock. For awards that are otherwise settled entirely in common stock, Edison International withholds or sells shares or substitutes cash awards to the extent necessary to satisfy applicable tax withholding obligations or government levies.
 Stock-based compensation expense is recognized, net of estimated forfeitures, on a straight-line basis over the requisite service period based on estimated fair values. For equity awards paid in common stock, fair value is determined at the grant date. For equity awards that have market conditions defined in the grants, expense is recognized based on grant date fair value if the requisite service period is fulfilled. However, with respect to the portion of the performance shares payable in common stock that are subject to financial performance conditions defined in the grants, the number of performance shares expected to be earned is subject to revision and updated at each reporting period, with a related adjustment to compensation expense.
 For awards granted to retirement-eligible participants, stock compensation expense is recognized on a prorated basis over the initial year. For awards granted to participants who become eligible for retirement during the requisite service period, stock compensation expense is recognized over the period between the date of grant and the date the participant first becomes eligible for retirement. Edison International and SCE estimate the number of awards that are expected to vest rather than account for forfeitures when they occur. Share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created. See Note 9 for further information.
 Employee Stock Purchase Plan
 The Edison International Employee Stock Purchase Plan ("ESPP"), effective beginning July 2021, allows eligible employees to make purchases of Edison International's common stock. The maximum aggregate numbers of shares that may be issued under the ESPP is 3,000,000 shares. Eligible employees may authorize payroll deductions of between 1 % and 10 % of their eligible base compensation, to purchase shares of common stock at 97 % of the market price on the last day of each six months offering period. An eligible employee may purchase up to $ 25,000 worth of Edison International's

 common stock per calendar year under the ESPP. The ESPP is considered noncompensatory and stock issuances under the ESPP are recorded directly in equity.
 SCE Dividends
 CPUC holding company rules require that SCE's dividend policy be established by the SCE Board of Directors on the same basis as if SCE were a stand-alone utility company, and that the capital requirements of SCE, as deemed to be necessary to meet SCE's electricity service obligations, shall receive first priority from the Boards of Directors of both Edison International and SCE. In addition, the CPUC regulates SCE's capital structure which limits the dividends it may pay to its shareholders.
 The common equity component of SCE's CPUC authorized capital structure is 52 % on a weighted average basis over the January 1, 2023 to December 31, 2025 compliance period ("Capital Structure Compliance Period"). The CPUC authorized capital structure differs from the capital structure calculated based on GAAP due to certain exclusions allowed by CPUC, including the impact of SCE's contributions to the Wildfire Insurance Fund under AB 1054.
 In August 2023, the CPUC issued a decision on SCE's application to the CPUC for an extension of the waiver of compliance with its equity ratio requirement that allows SCE to exclude from its equity ratio calculations (i) net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events and (ii) debt issued for the purpose of paying claims, and associated expenses, related to the 2017/2018 Wildfire/Mudslide Events up to an amount equal to the net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events. Under the decision, effective as of the beginning of the new cost of capital cycle on January 1, 2023, the CPUC also authorized SCE to exclude from its equity ratio calculations debt that exceeds the net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events due to the timing difference between the wildfire claims payment and the realization of the cash tax benefits. The temporary exclusion will lapse on August 31, 2025, or when determinations regarding cost recovery for both TKM and the Woolsey Fire are made, whichever comes earlier. In January 2025, the CPUC approved the TKM Settlement Agreement, under which SCE is allowed to permanently exclude any after-tax charges to equity associated with the costs disallowed or funded by shareholders in the TKM Settlement Agreement and the debt issued to finance those costs. If the CPUC has not made a determination regarding cost recovery related to the Woolsey Fire by August 31, 2025, SCE will file another application for a waiver of compliance with its equity ratio requirement. While the temporary exclusion is in place, SCE is required to notify the CPUC if an adverse financial event reduces SCE's spot equity ratio by more than one percent from the level most recently filed with the CPUC in the proceeding. The last spot equity ratio SCE filed with the CPUC in the proceeding did not exclude the then $ 1.8 billion net charge and was 45.2 % as of December 31, 2018 (at the time the common equity component of SCE's CPUC authorized capital structure was required to remain at or above 48 % on a weighted average basis over the applicable 37 -month period). SCE's spot equity ratio on December 31, 2018, would have been 48.7 % had the $ 1.8 billion net charge at December 31, 2018 been excluded, therefore SCE will notify the CPUC if its spot ratio drops below 47.7 % in any quarter.
 SCE monitors its compliance with the CPUC's equity ratio requirement based on the weighted average of the common equity component of SCE's CPUC authorized capital structure over the Capital Structure Compliance Period using its actual capital structure from the beginning of the Capital Structure Compliance Period through the reporting date together with forecasted performance and expected financing activities for the remainder of the Capital Structure Compliance Period. SCE expects to be compliant with its CPUC authorized capital structure at the end of the Capital Structure Compliance Period.
 SCE's ability to declare and pay common dividends may be restricted under the terms of its outstanding series of preference stock. For further information see Note 14.
 As a California corporation, SCE's ability to pay dividends is also governed by the California General Corporation Law. California law requires that for a dividend to be declared: (a) retained earnings must equal or exceed the proposed dividend, or (b) immediately after the dividend is made, the value of the corporation's assets must exceed the value of its liabilities plus amounts required to be paid, if any, in order to liquidate stock senior to the shares receiving the dividend. Additionally, a California corporation may not declare a dividend if it is, or as a result of the dividend would be, likely to be unable to meet its liabilities as they mature. Prior to declaring dividends, the SCE Board of Directors evaluates available information, including when applicable, information pertaining to wildfire events, to ensure that the California law requirements for the declarations are met. On February 27, 2025, SCE declared a dividend to Edison International of $ 430 million.
 The timing and amount of future dividends are also dependent on a number of other factors including SCE's requirements to fund other obligations and capital expenditures, and its ability to access the capital markets and generate operating cash flows and earnings. If SCE incurs significant costs related to catastrophic wildfires and is unable to recover such costs through insurance, the Wildfire Insurance Fund (for fires after July 12, 2019), or from customers or is unable to access

 capital markets on reasonable terms, SCE may be limited in its ability to pay future dividends to Edison International and its preference shareholders.
 Edison International Dividend
 Edison International's ability to declare and pay common dividends may be restricted under the terms of its outstanding preferred stock. For further information see Note 14.
 In December 2024, Edison International declared a 6.1 % increase to the annual dividend rate from $ 3.12 per share to $ 3.31 per share. On February 27, 2025, Edison International declared a dividend of $ 0.8275 per share to be paid on April 30, 2025. Edison International intends to maintain its target payout ratio of 45 % – 55 % of SCE's core earnings.
 Earnings Per Share
 Edison International computes earnings per common share ("EPS") using the two-class method, which is an earnings allocation formula that determines EPS for each class of common stock and participating security. Edison International's participating securities are stock-based compensation awards, payable in common shares, which earn dividend equivalents on an equal basis with common shares once the awards are vested. See Note 9 and Note 14 for further information.
 EPS attributable to Edison International common shareholders was computed as follows:

 (in millions, except per-share amounts)
 2024
 2023
 2022

 Basic earnings per share:

 Net income available to common shareholders
 $
 1,284
 $
 1,197
 $

 Weighted average common shares outstanding

 Basic earnings per share
 $
 3.33
 $
 3.12
 $
 1.61

 Diluted earnings per share:

 Net income available to common shareholders
 $
 1,284
 $
 1,197
 $

 Income impact of assumed conversions

 Net income available to common shareholders and assumed conversions
 $
 1,285
 $
 1,198
 $

 Weighted average common shares outstanding

 Incremental shares from assumed conversions

 Adjusted weighted average shares – diluted

 Diluted earnings per share
 $
 3.31
 $
 3.11
 $
 1.60

 In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 1,533,982, 3,771,766, and 5,839,549 of common stock for the years ended December 31, 2024, 2023, and 2022, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.
 Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from the differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets.
 Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Interest income, interest expense, and penalties associated with income taxes are generally reflected in "Income tax expense (benefit)" on the consolidated statements of income.
 Investment tax credits are generally deferred and amortized to income tax expense over the lives of the related properties. The scope of projects eligible for investment tax credits was expanded in 2023 to include standalone energy storage projects. The Inflation Reduction Act provided an election that permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the related property.
 Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its subsidiaries.

 Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis.
 Severance Costs
 Severance costs are recorded when it is probable that employees will be entitled to benefits under an existing plan and the amount can be reasonably estimated. As a result of current and probable reductions in workforce, SCE recorded estimated severance costs of $ 53 million for the year ended December 31, 2024. Severance costs are included in "Operation and maintenance" on the consolidated statements of income. The severance costs are partially offset by $ 3 million expected FERC recovery, which is recorded in "Operating Revenue" on the consolidated statements of income.
 New Accounting Guidance
 Accounting Guidance Adopted
 In November 2023, the FASB issued an accounting standards update to enhance the disclosures related to public entities' reportable segments. The new guidance requires an entity with only one reportable segment to include all the required segment disclosures. Edison International and SCE each have one reportable segment, and have adopted this guidance for the year ended December 31, 2024. See "Segment Information" above for further information.
 Accounting Guidance Not Yet Adopted
 In December 2023, the FASB issued an accounting standards update requiring public entities to provide more disclosures primarily related to the income tax rate reconciliation and income taxes paid. The guidance also eliminates certain existing disclosure requirements related to uncertain tax positions and unrecognized deferred tax liabilities. The guidance is effective for annual periods after January 1, 2025 with early adoption permitted. The guidance is applied prospectively. Edison International and SCE are currently evaluating the impact of the new guidance.
 In November 2024, the FASB issued an accounting standards update requiring public entities to provide disaggregated disclosure of income statement expenses. The guidance does not change the expense captions an entity presents on the face of the income statement, rather, it requires disaggregation of certain expense captions into specified categories in disclosures within the footnotes to the financial statements. The guidance is effective for annual disclosure for the year ended December 31, 2027 and subsequent interim periods with early adoption permitted. The guidance is applied prospectively. Edison International and SCE are currently evaluating the impact of the new guidance.

 Note 2. Property, Plant and Equipment
 SCE's utility property, plant and equipment included in the consolidated balance sheets is composed of the following:

 2024
 2023

 Distribution
 $
 37,093
 $
 34,573

 Transmission
 19,189
 18,526

 Generation
 4,217
 3,593

 General plant and other
 7,046
 6,383

 Accumulated depreciation
 ( 14,207)
 ( 12,910)

 53,338
 50,165

 Construction work in progress
 5,585
 5,590

 Nuclear fuel, at amortized cost

 Total utility property, plant and equipment
 $
 59,047
 $
 55,877

 Capitalized Software Costs
 SCE capitalizes costs incurred during the application development stage of internal use software projects to property, plant and equipment. SCE amortizes capitalized software costs ratably over their useful lives, primarily 5 and 7 year lives, commencing upon operational use. Capitalized software costs, included in general plant and other above, was $ 2.5 billion and $ 2.1 billion at December 31, 2024 and 2023, respectively, and accumulated amortization was $ 1.1 billion and $ 0.9 billion, at December 31, 2024 and 2023, respectively. Amortization expense for capitalized software was $ 416 million, $ 358 million, and $ 344 million in 2024, 2023, and 2022, respectively. At December 31, 2024, amortization expense is estimated to be $ 428 million, $ 371 million, $ 288 million, $ 186 million, and $ 72 million for 2025 through 2029, respectively.

 Jointly Owned Utility Projects
 SCE owns undivided interests in transmission and generating assets for which each participant provides its own financing. SCE's proportionate share of these assets is reflected in the consolidated balance sheets and included in the above table. SCE's proportionate share of expenses for each project is reflected in the consolidated statements of income.
 The following is SCE's investment in each asset as of December 31, 2024:

 Plant in
Service
 Construction
Work in
Progress
 Accumulated
Depreciation
 Nuclear Fuel
(at amortized cost)
 Total
 Ownership
Interest

 Transmission systems:

 Eldorado
 $
 $
 $
 ( 71)
 $
 —
 $
 %

 Pacific Intertie
 ( 121)
 —
 %

 Generating station:

 Palo Verde (nuclear)
 2,249
 ( 1,694)
 %

 Total
 $
 3,053
 $
 $
 ( 1,886)
 $
 $
 1,401

 In addition to the jointly owned assets in the table above, SCE has ownership interests in jointly owned power poles with other companies.

 Note 3. Variable Interest Entities
 A VIE is defined as a legal entity that meets any of the following conditions: (1) the total equity investment at risk is not sufficient to fund the entity's activities without additional subordinated financial support, (2) the equity holders as a group, lack any of the following characteristics: the power to direct activities that most significantly impact the entity's economic performance, substantive voting rights, the obligation to absorb losses, or the right to receive the expected residual returns of the entity. The primary beneficiary is identified as the variable interest holder that has both the power to direct the activities of the VIE that most significantly impact the entity's economic performance, and the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The primary beneficiary is required to consolidate the VIE. Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs.
 Variable Interest in VIEs that are Consolidated
 SCE Recovery Funding LLC is a bankruptcy remote, wholly owned special purpose subsidiary of SCE, formed for the purpose of issuing securitized bonds related to SCE's AB 1054 Excluded Capital Expenditures. This entity is a VIE because its equity investment is insufficient to support its operations. The most significant activity of SCE Recovery Funding LLC is to service the securitized bonds according to the decisions made by SCE. Therefore, SCE is determined to be the primary beneficiary and consolidates SCE Recovery Funding LLC.
 SCE Recovery Funding LLC issued a total of $ 1.6 billion of securitized bonds. The proceeds were used to acquire SCE's right, title and interest in and to non-bypassable rates and other charges to be collected from certain existing and future customers in SCE's service area ("Recovery Property"), associated with the AB 1054 Excluded Capital Expenditures, until the bonds are paid in full, and all financing costs have been recovered. The securitized bonds are secured by the Recovery Property and cash collections from the non-bypassable rates and other charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to SCE. For further details, see Note 5.
 The following table summarizes the impact of SCE Recovery Funding LLC on SCE's and Edison International's consolidated balance sheets.

 2024
 2023

 Other current assets
 $
 $

 Regulatory assets: non-current
 1,512
 1,558

 Regulatory liabilities: current

 Current portion of long-term debt1

 Other current liabilities

 Long-term debt1

 1,468
 1,515

 1The bondholders have no recourse to SCE. The long-term debt balance is net of unamortized debt issuance costs.
 Variable Interest in VIEs that are not Consolidated
 Power Purchase Agreements
 SCE has certain PPAs where the counterparty entities meet one or both of the VIE conditions discussed above and in which SCE has variable interests, including: agreements through which SCE provides natural gas to fuel the plants, fixed price contracts for renewable energy, and resource adequacy agreements that allow purchase of energy at fixed prices upon the seller's election. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is typically the operation and maintenance of the power plants, which SCE does not perform. Therefore, SCE has concluded that it is not the primary beneficiary of any of these VIEs because it does not control the commercial and operating activities that most significantly impact the economic performance of these entities.
 As of the balance sheet date, the carrying amount of assets and liabilities included in SCE's consolidated balance sheet that relate to involvement with VIEs that are not consolidated, result from amounts due under the PPAs. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees, or other commitments associated with these contracts other than the purchase commitments described in Note 12. As a result, there is no significant potential exposure to loss to SCE from its variable interest in these VIEs. The aggregate contracted capacity dedicated to SCE from these VIE projects was 5,200 MW and 3,343 MW at December 31, 2024 and 2023, respectively, and the amounts that SCE paid to these projects were $ 778 million and $ 528 million for the years ended December 31, 2024 and 2023, respectively. These amounts are recoverable in customer rates, subject to a reasonableness review.

 Note 4. Fair Value Measurements
 Recurring Fair Value Measurements
 Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (referred to as an "exit price"). Fair value of an asset or liability considers assumptions that market participants would use in pricing the asset or liability, including assumptions about nonperformance risk. As of December 31, 2024 and 2023, nonperformance risk was not material for Edison International or SCE.
 Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.
 Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds, and money market funds.
 Level 2 – Edison International's and SCE's Level 2 assets and liabilities include fixed income securities, primarily consisting of U.S. government and agency bonds, municipal bonds and corporate bonds, and over-the-counter commodity derivatives. The fair value of fixed income securities is determined using a market approach by obtaining quoted prices for similar assets and liabilities in active markets and inputs that are observable, either directly or indirectly, for substantially the full term of the instrument.
 The fair value of SCE's over-the-counter commodity derivative contracts is determined using an income approach. SCE uses standard pricing models to determine the net present value of estimated future cash flows. Inputs to the pricing models include forward published or posted clearing prices from an exchange (Intercontinental Exchange) for similar instruments and discount rates. A primary price source that best represents trade activity for each market is used to develop observable forward market prices in determining the fair value of these positions. Broker quotes, prices from exchanges or comparison to executed trades are used to validate and corroborate the primary price source. These price quotations reflect mid-market prices (average of bid and ask) and are obtained from sources believed to provide the most liquid market for the commodity.
 Level 3 – This level consists of CRRs, which are derivative contracts that trade infrequently with significant unobservable inputs (CAISO CRR auction prices). SCE employs a market valuation approach of utilizing historical CRR prices as a proxy for forward prices. Edison International Parent and Other does not have any Level 3 assets and liabilities.
 Assumptions are made in order to value derivative contracts in which observable inputs are not available. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs, and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted

 when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of derivative instruments.
 SCE
 The following table sets forth assets and liabilities of SCE that were accounted for at fair value by level within the fair value hierarchy:

 Level 3
 Netting
 and
 Collateral1

 Total

 Assets at fair value

 Derivative contracts
 $
 —
 $
 $
 $
 ( 1)
 $

 Other
 —
 —
 —

 Nuclear decommissioning trusts:

 Stocks2

 1,631
 —
 —
 —
 1,631

 Fixed Income3

 1,618
 —
 —
 2,593

 Short-term investments, primarily cash equivalents
 —
 —

 Subtotal of nuclear decommissioning trusts4

 2,734
 1,657
 —
 —
 4,391

 2,734
 1,680
 ( 1)
 4,625

 Liabilities at fair value

 Derivative contracts
 —
 —
 ( 47)
 —

 Total liabilities
 —
 —
 ( 47)
 —

 Net assets
 $
 2,734
 $
 1,633
 $
 $
 $
 4,625

 Level 3
 Netting
 and
 Collateral1

 Total

 Assets at fair value

 Derivative contracts
 $
 —
 $
 $
 $
 ( 3)
 $

 Money market funds and other
 —
 —

 Nuclear decommissioning trusts:

 Stocks2

 1,658
 —
 —
 —
 1,658

 Fixed Income3

 1,421
 —
 —
 2,344

 Short-term investments, primarily cash equivalents
 —
 —

 Subtotal of nuclear decommissioning trusts4

 2,750
 1,525
 —
 —
 4,275

 2,828
 1,550
 ( 3)
 4,466

 Liabilities at fair value

 Derivative contracts
 —
 —
 ( 77)
 —

 Total liabilities
 —
 —
 ( 77)
 —

 Net assets
 $
 2,828
 $
 1,473
 $
 $
 $
 4,466

 1Represents the netting of assets and liabilities under master netting agreements and cash collateral.
 2Approximately 75 % of SCE's equity investments were in companies located in the United States at December 31, 2024 and 2023.
 3Includes corporate bonds, which were diversified by the inclusion of collateralized mortgage obligations and other asset backed securities of $ 94 million and $ 106 million at December 31, 2024 and 2023, respectively.
 4Excludes net payables of $ 105 million and $ 102 million at December 31, 2024 and 2023, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

 SCE Fair Value of Level 3
 The following table sets forth a summary of changes in SCE's fair value of Level 3 net derivative assets and liabilities:

 2024
 2023

 Fair value of net assets at beginning of period
 $
 $

 Sales
 ( 1)
 ( 1)

 Settlements
 ( 40)

 Total realized/unrealized gains, net of losses1

 Fair value of net assets at end of period
 $
 $

 1Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities.
 There were no material transfers into or out of Level 3 during 2024 and 2023.
 The following table sets forth the significant unobservable inputs used to determine fair value for Level 3 CRR assets and liabilities:

 Significant
Unobservable
Input
 Range
(per MWh)
 Weighted
Average
(per MWh)

 Assets
 Liabilities

 $
 $
 —
 CAISO CRR auction prices
 $( 4.64) - $ 50,048.16

 $
 27.20

 —
 CAISO CRR auction prices
 ( 6.44) - 16,574.36

 2.74

 Level 3 Fair Value Uncertainty
 For CRRs, increases or decreases in CAISO auction prices would result in higher or lower fair value, respectively.
 Nuclear Decommissioning Trusts
 SCE's nuclear decommissioning trust investments include equity securities, U.S. treasury securities and other fixed income securities. Equity and treasury securities are classified as Level 1 as fair value is determined by observable market prices in active or highly liquid and transparent markets. The remaining fixed income securities are classified as Level 2. The fair value of these financial instruments is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information. There are no securities classified as Level 3 in the nuclear decommissioning trusts.
 SCE's investment policies and CPUC requirements place limitations on the types and investment grade ratings of the securities that may be held by the nuclear decommissioning trust funds. These policies restrict the trust from holding alternative investments and limit the trust funds' exposures to investments in highly illiquid markets. With respect to equity and fixed income securities, the trustee obtains prices from third-party pricing services which SCE is able to independently corroborate as described below. The trustee monitors prices supplied by pricing services, including reviewing prices against defined parameters' tolerances and performs research and resolves variances beyond the set parameters. SCE corroborates the fair values of securities by comparison to other market-based price sources obtained by SCE's investment managers. Differences outside established thresholds are followed-up with the trustee and resolved. For each reporting period, SCE reviews the trustee determined fair value hierarchy and overrides the trustee level classification when appropriate. See Note 10 for more information on nuclear decommissioning trusts.
 Edison International Parent and Other assets measured at fair value and classified as Level 1 consisted of money market funds of $ 101 million and $ 121 million at December 31, 2024 and 2023, respectively. Assets measured at fair value and classified as Level 2 were immaterial at December 31, 2024 and 2023. There were no securities classified as Level 3 for Edison International Parent and Other at December 31, 2024 and 2023.

 Fair Value of Debt Recorded at Carrying Value
 The carrying value and fair value of Edison International's and SCE's long-term debt (including current portion of long-term debt) are as follows:

 Carrying
 Value1

 Fair
 Value2

 Carrying
 Value1

 Fair
 Value2

 $
 35,583
 $
 33,160
 $
 33,013
 $
 31,315

 SCE
 30,515
 27,994
 28,494
 26,712

 1Carrying value is net of debt issuance costs.
 2The fair value of long-term debt is classified as Level 2.

 Note 5. Debt and Credit Agreements
 Long-Term Debt
 The following table summarizes long-term debt (rates and terms are as of December 31, 2024) of Edison International and SCE:

 2024
 2023

 Edison International Parent and Other:

 Debentures and notes:

 2025 – 2054 ( 4.125 % to 8.125 %)

 $
 5,100
 $
 4,550

 ( 800)
 ( 500)

 Unamortized debt discount/premium and issuance costs, net
 ( 32)
 ( 31)

 Total Edison International Parent and Other
 4,268
 4,019

 SCE:

 First and refunding mortgage bonds:

 2025 – 2053 ( 1.20 % to 6.05 %)

 27,400
 24,700

 Pollution-control bonds:

 2028 – 2035 ( 1.45 % to 4.50 %)

 Debentures and notes:

 2029 – 2053 ( 5.06 % to 6.65 %)

 Senior secured recovery bonds1:

 2028 – 2047 ( 0.86 % to 5.11 %)

 1,532
 1,579

 Other long-term debt2

 1,322

 ( 1,249)
 ( 2,197)

 Unamortized debt discount/premium and issuance costs, net
 ( 181)
 ( 165)

 Total SCE
 29,266
 26,297

 Total Edison International
 $
 33,534
 $
 30,316

 1The senior secured recovery bonds are payable only from and secured by the Recovery Property at SCE Recovery Funding LLC, and do not constitute a debt or other legal obligation of, or interest in, SCE or any of its affiliates, except for SCE Recovery Funding LLC. For further details, see Note 3.
 2Subsequent to December 31, 2024 and 2023, SCE issued first and refunding mortgage bonds which were used to partially pay down its commercial paper balance. As a result, SCE included the paydown amount of $ 706 million and $ 722 million in other long-term debt at December 31, 2024 and 2023, respectively. The 2023 amount also includes a $ 600 million term loan with an interest rate of adjusted term secured overnight financing rate ("SOFR") plus 0.90 % that matured in 2024.
 Edison International and SCE long-term debt maturities over the next five years are as follows:

 Edison
International
 SCE

 2025
 $
 2,049
 $
 1,249

 2026
 1,900
 1,900

 2027
 2,501
 1,901

 2028
 2,942
 1,792

 2029
 3,363
 2,313

 Debt Financing Subsequent to December 31, 2024
 In January 2025, SCE issued $ 850 million of 5.45 % first and refunding mortgage bonds due in 2035 and $ 650 million of 5.90 % first and refunding mortgage bonds due in 2055. The proceeds were used to repay commercial paper borrowings and for general corporate purposes.
 Liens and Security Interests
 Almost all of SCE's properties are subject to a trust indenture lien. SCE has pledged first and refunding mortgage bonds as collateral for borrowed funds obtained from pollution-control bonds issued by government agencies. SCE has a debt covenant that requires a debt to total capitalization ratio to be less than or equal to 0.65 to 1. At December 31, 2024, SCE's debt to total capitalization ratio was 0.58 to 1 and was in compliance with all other financial covenants that affect access to capital. Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.70 to 1. At December 31, 2024, Edison International consolidated debt to total capitalization ratio was 0.65 to 1.
 Credit Agreements and Short-Term Debt
 The following table summarizes the status of the credit facilities at December 31, 2024:

 (in millions, except for rates)

 Borrower
 Termination Date
 SOFR plus (bps)
 Commitment
 Outstanding borrowings
 Outstanding letters of credit
 Amount available

 Edison International Parent1, 3

 May 2028
 $
 1,500
 $
 $
 —
 $
 1,055

 SCE2, 3

 May 2028
 3,350
 1,260
 2,084

 Total Edison International
 $
 4,850
 $
 1,705
 $
 $
 3,139

 1At December 31, 2024 and 2023, Edison International Parent had $ 444 million and $ 246 million outstanding commercial paper, net of discount of $ 1 million and zero, at a weighted-average interest rate of 4.86 % and 5.82 %, respectively.
 2At December 31, 2024 and 2023, SCE had $ 1,259 million and $ 1,554 million outstanding commercial paper, net of discount of $ 1 million and $ 4 million, at a weighted-average interest rate of 4.95 % and 5.82 %, respectively. This includes $ 706 million and $ 722 million, at December 31, 2024 and 2023, respectively, outstanding commercial paper reclassified from "Short-term debt" to "Long-term debt" on the consolidated balance sheets, due to subsequent debt refinancing.
 3 The aggregate maximum principal amount under the Edison International Parent and SCE revolving credit facilities may be increased up to $ 2.0 billion and $ 4.0 billion, respectively, provided that additional lender commitments are obtained. In May 2024, Edison International Parent and SCE amended their credit facilities to extend the maturity date to May 2028, with additional one-year extension options.
 Uncommitted Letters of Credit
 SCE has agreements with certain lenders for bilateral unsecured standby letters of credit ("SBLC") with a total capacity of $ 625 million that is uncommitted and supported by reimbursement agreements. The SBLCs are not subject to any collateral or security requirements. At December 31, 2024, SCE had $ 118 million in standby letters of credit outstanding under these agreements, which expire between January and December 2025. The unused capacity under these agreements was $ 507 million.

 Note 6. Derivative Instruments
 Derivative financial instruments are used to manage exposure to commodity price risk resulting from SCE's electricity and natural gas procurement activities. The risks of fluctuating commodity prices are managed in part by entering into forward commodity transactions, including options, swaps, and futures. To mitigate credit risk from counterparties in the event of

 nonperformance, master netting agreements are used whenever possible, and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.
 Certain power and gas contracts contain a provision that requires SCE to maintain an investment grade rating from the major credit rating agencies, referred to as a credit-risk-related contingent feature. If SCE's credit rating were to fall below investment grade, SCE may be required to post additional collateral to cover derivative liabilities and the related outstanding payables. The fair value of these derivative contracts and any related collateral were immaterial as of December 31, 2024 and 2023.
 SCE presents its derivative assets and liabilities, recorded at fair value, on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are also offset against margin and cash collateral deposits. See Note 4 for a discussion of fair value of derivative instruments.
 The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:

 Derivative Assets
 Short-Term1

 Derivative Liabilities
 Short-Term2

 Commodity derivative contracts

 Gross amounts recognized
 $
 $

 Gross amounts offset in the consolidated balance sheets
 ( 1)
 ( 1)

 Cash collateral posted
 —
 ( 46)

 Net amounts presented in the consolidated balance sheets
 $
 $
 —

 Derivative Assets
 Short-Term1

 Derivative Liabilities
 Short-Term2

 Commodity derivative contracts

 Gross amounts recognized
 $
 $

 Gross amounts offset in the consolidated balance sheets
 ( 3)
 ( 3)

 Cash collateral posted
 —
 ( 74)

 Net amounts presented in the consolidated balance sheets
 $
 $
 —

 1Included in "Other current assets" on SCE's consolidated balance sheets.
 2 Included in "Other current liabilities" on SCE's consolidated balance sheets.
 At December 31, 2024, SCE posted $ 74 million of cash collateral, of which $ 46 million was offset against derivative liabilities and $ 28 million was reflected in "Other current assets" on the consolidated balance sheets.
 Financial Statement Impact of Derivative Instruments
 SCE recognizes realized gains and losses on derivative instruments as purchased power expense and unrealized gains and losses as regulatory assets or liabilities. Both realized and unrealized gains and losses are expected to be recovered from customers and therefore do not affect earnings. Cash flows from derivative activities, including cash collateral, are reported in cash flows from operating activities in SCE's consolidated statements of cash flows.
 The following table summarizes the gains/(losses) of SCE's economic hedging activity:

 2024
 2023
 2022

 Realized
 $
 ( 409)
 $
 ( 14)
 $

 Unrealized
 ( 322)

 Notional Volumes of Derivative Instruments
 The following table summarizes the notional volumes of derivatives used for SCE's economic hedging activities:

 Economic Hedges

 Unit of
Measure

 Commodity
 2024
 2023

 Electricity options, swaps and forwards
 Gigawatt hours
 3,295
 3,494

 Natural gas options, swaps and forwards
 Billion cubic feet

 Congestion revenue rights
 Gigawatt hours
 8,141
 35,011

 Note 7. Revenue
 The following table is a summary of SCE's revenue:

 2024
 2023
 2022

 Revenue from contracts with customers

 Commercial
 $
 8,000
 $
 7,333
 $
 7,028

 Residential
 7,060
 6,421
 6,707

 Other
 3,335
 3,266
 3,025

 Total revenue from contracts with customer1

 18,395
 17,020
 16,760

 Alternative revenue program and other2

 ( 848)
 ( 745)

 Total operating revenue
 $
 17,547
 $
 16,275
 $
 17,172

 1At December 31, 2024 and 2023, SCE's receivables related to contracts from customers were $ 2.9 billion and $ 2.5 billion, which included accrued unbilled revenue of $ 845 million and $ 741 million, respectively.
 2Includes differences between revenues from contracts with customers and authorized levels for certain CPUC and FERC revenues.
 Deferred Revenue
 As of December 31, 2024, SCE has deferred revenue of $ 354 million related to the sale of the use of transfer capability of West of Devers transmission line, of which $ 13 million and $ 341 million are included in "Other current liabilities" and "Other deferred credits and other long-term liabilities," respectively, on SCE's consolidated balance sheets. The deferred revenue is amortized straight-line over a period of 30 years starting 2021.

 Note 8. Income Taxes
 Current and Deferred Taxes
 The components of income tax expense (benefit) by location of taxing jurisdiction are:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Current:

 Federal
 $
 $
 —
 $
 $
 $
 —
 $
 —

 State
 —

 —

 Deferred:

 Federal
 ( 103)
 ( 44)

 State
 ( 50)
 ( 74)
 ( 49)
 ( 67)

 ( 177)
 ( 111)

 Total
 $
 $
 $
 ( 162)
 $
 $
 $
 ( 109)

 The components of net accumulated deferred income tax liability are:

 SCE

 2024
 2023
 2024
 2023

 Deferred tax assets:

 Property
 $
 $
 $
 $

 Wildfire-related1

 Nuclear decommissioning trust assets in excess of nuclear ARO liability

 Loss and credit carryforwards2

 3,703
 3,486
 2,242
 2,103

 Regulatory balances

 Pension and postretirement benefits other than pensions, net

 Leases

 Other

 Sub-total
 6,512
 6,373
 4,928
 4,857

 Less: valuation allowance3

 —
 —

 Total
 6,495
 6,356
 4,928
 4,857

 Deferred tax liabilities:

 Property
 11,220
 10,627
 11,202
 10,611

 Regulatory balances
 1,299
 1,450
 1,299
 1,450

 Nuclear decommissioning trust assets

 Leases

 Other

 Total
 13,414
 12,989
 13,364
 12,944

 Accumulated deferred income tax liability, net4

 $
 6,919
 $
 6,633
 $
 8,436
 $
 8,087

 1Relates to estimated losses accrual for wildfire-related claims, net of expected recoveries from insurance and FERC customers, and contributions to the Wildfire Insurance Fund. For further information, see Note 12 and Note 1.
 2As of December 31, 2024, unrecognized tax benefits of $ 397 million and $ 327 million for Edison International and SCE, respectively, are presented net against the deferred tax asset for the loss and tax credit carryforwards. As of December 31, 2023, the unrecognized tax benefits netted against deferred tax assets and tax credit carryforwards were $ 363 million and $ 299 million for Edison International and SCE, respectively.
 3As of December 31, 2024 and 2023, Edison International has recorded $ 17 million valuation allowance on deferred tax assets. The $ 17 million valuation allowance is related to non-California state net operating loss carryforwards which are expected to expire before being utilized.
 4Included in "Deferred income taxes and credits" on the consolidated balance sheets.

 Net Operating Loss and Tax Credit Carryforwards
 The amounts of net operating loss and tax credit carryforwards (after-tax) are as follows:

 SCE

 Loss
Carryforwards
 Credit
Carryforwards
 Loss
Carryforwards
 Credit
Carryforwards

 Expire in 2025
 $
 $
 —
 $
 $
 —

 Expire between 2026 to 2029
 —
 —

 Expire between 2030 to 2044
 1,719

 No expiration date1

 1,623
 1,448

 Total
 $
 3,377
 $
 $
 2,253
 $

 1Under the Tax Cut and Jobs Act signed into law on December 22, 2017 ("Tax Reform"), net operating losses generated after December 31, 2017 can carryforward indefinitely.
 Edison International consolidates for federal income tax purposes, but not for financial accounting purposes, a group of wind projects referred to as Capistrano Wind. The amount of net operating loss and tax credit carryforwards recognized as part of deferred income taxes includes $ 107 million and $ 106 million related to Capistrano Wind for 2024 and 2023, respectively. The tax attributes not utilized as of December 31, 2024 will be available for the Edison International consolidated group to utilize in the future. When the remaining Capistrano tax attributes are used in the future by Edison International, payments will be made to those entities under a tax allocation agreement. Under the tax allocation agreement, Edison International has recorded a corresponding liability as part of other long-term liabilities related to its obligation to make payments to Capistrano Wind when these tax benefits are realized.
 Effective Tax Rate
 The table below provides a reconciliation of income tax expense computed at the federal statutory income tax rate to the income tax provision:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Income from operations before income taxes
 $
 1,563
 $
 1,515
 $
 $
 1,914
 $
 1,781
 $

 Provision for income tax at federal statutory rate of 21 %

 (Decrease) increase in income tax from:

 State tax, net of federal income tax effect
 ( 24)
 ( 70)
 —
 ( 57)

 Property-related
 ( 279)
 ( 205)
 ( 219)
 ( 279)
 ( 205)
 ( 219)

 Corporate-owned life insurance cash surrender value
 ( 9)
 ( 8)
 ( 9)
 ( 9)
 ( 8)
 ( 9)

 Other
 —
 ( 3)
 —
 ( 1)

 Total income tax expense (benefit)
 $
 $
 $
 ( 162)
 $
 $
 $
 ( 109)

 Effective tax rate
 1.1
 %
 7.1
 %
 ( 24.5)
 %
 6.3
 %
 10.3
 %
 ( 12.9)
 %

 The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates. For further information, see Note 11.
 In the third quarter of 2024, SCE generated an investment tax credit of approximately $ 231 million, primarily from 200 MW and 112.5 MW utility owned storage projects. The tax benefits associated with these credits will be recognized and returned to customers as the credits are utilized.

 Under the Inflation Reduction Act of 2022, 15% corporate alternative minimum tax ("CAMT") is imposed on corporations with average adjusted financial statement income exceeding $1.0 billion over a specified 3-year period. Both Edison International and SCE are not subject to CAMT in 2024.
 Accounting for Uncertainty in Income Taxes
 Authoritative guidance related to accounting for uncertainty in income taxes requires an enterprise to recognize, in its financial statements, the best estimate of the impact of a tax position by determining if the weight of available evidence indicates it is more likely than not, based solely on the technical merits, that the position will be sustained upon examination. The guidance requires the disclosure of all unrecognized tax benefits, which includes both the reserves recorded for tax positions on filed tax returns and the unrecognized portion of affirmative claims.
 Unrecognized Tax Benefits
 The following table provides a reconciliation of unrecognized tax benefits:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Balance at January 1,
 $
 $
 $
 $
 $
 $

 Tax positions taken during the current year:

 Increases

 Tax positions taken during a prior year:

 Increases
 —
 —
 —

 Decreases1

 ( 34)
 ( 294)
 ( 21)
 ( 27)
 ( 25)
 ( 20)

 Balance at December 31,
 $
 $
 $
 $
 $
 $

 1 The Edison International decrease in 2023 was mainly related to a write-off of a reserve for a claim related to the Edison Mission Energy bankruptcy.
 As of December 31, 2024, if recognized, $ 72 million of unrecognized tax benefits would impact Edison International's effective tax rate and $ 66 million of the unrecognized tax benefits would impact SCE's effective tax rate.
 Tax Disputes
 Tax years that remain open for examination by the Internal Revenue Service and Franchise Tax Board are 2021 – 2023 and 2013 – 2018 & 2020 - 2023, respectively.
 Accrued Interest and Penalties
 The total amount of accrued interest and penalties related to income tax liabilities are:

 SCE

 2024
 2023
 2024
 2023

 Accrued interest and penalties
 $
 —
 $
 —
 $
 $

 The net after-tax interest and penalties recognized in income tax (benefit) expense are:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Net after-tax interest and penalties tax expense
 $
 —
 $
 —
 $
 —
 $
 $
 $

 Note 9. Compensation and Benefit Plans
 Employee Savings Plan
 The 401(k) defined contribution savings plan is designed to supplement employees' retirement income. The employer contributions were as follows:

 Edison
International
 SCE

 2024
 $
 $

 2023

 2022

 Pension Plans and Postretirement Benefits Other Than Pensions
 Pension Plans
 Noncontributory defined benefit pension plans (some with cash balance features) cover most employees meeting minimum service requirements. Employees hired by the participating companies on or after December 31, 2017 are no longer eligible to participate in the pension plan. In lieu of that, an additional non-contributory employer contribution is deposited into the Edison 401(k) Savings Plan. SCE recognizes pension expense for its nonexecutive plan as calculated by the actuarial method used for ratemaking. The expected contributions (all by the employer) for Edison International and SCE are approximately $ 44 million and $ 15 million, respectively, for the year ending December 31, 2025. The majority of annual contributions made by SCE to its pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms.
 The funded position of Edison International's pension is sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's pension are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, unrealized losses equal to the unfunded status are recorded to a regulatory asset and unrealized gains equal to the funded status are recorded to a regulatory liability. See Note 11 for further information.

 Information on pension plan assets and benefit obligations is shown below.

 SCE

 2024
 2023
 2024
 2023

 Change in projected benefit obligation

 Projected benefit obligation at beginning of year
 $
 3,647
 $
 3,524
 $
 3,278
 $
 3,159

 Service cost

 Interest cost

 Actuarial (gain) loss
 ( 59)
 ( 47)

 Benefits paid
 ( 230)
 ( 254)
 ( 198)
 ( 222)

 Projected benefit obligation at end of year
 $
 3,636
 $
 3,647
 $
 3,289
 $
 3,278

 Change in plan assets

 Fair value of plan assets at beginning of year
 $
 3,609
 $
 3,462
 $
 3,415
 $
 3,275

 Actual return on plan assets

 Employer contributions

 Benefits paid
 ( 230)
 ( 254)
 ( 198)
 ( 222)

 Fair value of plan assets at end of year
 3,608
 3,609
 3,416
 3,415

 (Underfunded)/Overfunded status at end of year
 $
 ( 28)
 $
 ( 38)
 $
 $

 Amounts recognized in the consolidated balance sheets consist of 1:

 Long-term assets
 $
 $
 $
 $

 Current liabilities
 ( 27)
 ( 30)
 ( 1)
 ( 2)

 Long-term liabilities
 ( 167)
 ( 177)
 ( 9)
 ( 10)

 $
 ( 28)
 $
 ( 38)
 $
 $

 Amounts recognized in accumulated other comprehensive loss consist of:

 Net loss

 $
 $
 $
 $

 Amounts recognized as a regulatory liability
 ( 146)
 ( 159)
 ( 133)
 ( 159)

 Accumulated benefit obligation at end of year
 $
 3,508
 $
 3,495
 $
 3,172
 $
 3,136

 Pension plans with plan assets in excess of an accumulated benefit obligation:

 Projected benefit obligation
 3,636
 3,647
 3,289
 3,278

 Accumulated benefit obligation
 3,508
 3,495
 3,172
 3,136

 Fair value of plan assets
 3,608
 3,609
 3,416
 3,415

 Weighted average assumptions used to determine obligations at end of year:

 Discount rate
 5.56 %
 5.04 %
 5.56 %
 5.04 %

 Rate of compensation increase
 4.00 %
 4.00 %
 4.00 %
 4.00 %

 1 The SCE liability excludes a long-term payable due to Edison International Parent of $ 88 million and $ 94 million at December 31, 2024 and 2023, respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent.
 For Edison International and SCE, respectively, the 2024 actuarial gains are primarily related to $ 159 million and $ 146 million from an increase of 52 basis points in the discount rate (from 5.04 % as of December 31, 2023 to 5.56 % as of December 31, 2024). For Edison International and SCE, respectively, the 2023 actuarial losses are primarily related to $ 96 million and $ 92 million in losses from a decrease of 32 basis points in the discount rate (from 5.36 % as of December 31, 2022 to 5.04 % as of December 31, 2023).

 Net periodic pension expense components are:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Service cost
 $
 $
 $
 $
 $
 $

 Non-service cost (benefit)

 Interest cost

 Expected return on plan assets
 ( 232)
 ( 214)
 ( 227)
 ( 219)
 ( 202)
 ( 215)

 Settlement costs
 —
 —
 —
 —

 Amortization of prior service cost
 —
 —
 —
 —
 —
 —

 Amortization of net loss

 Regulatory adjustment
 ( 23)
 ( 47)
 ( 22)
 ( 47)

 Total non-service benefit1

 ( 76)
 ( 78)
 ( 101)
 ( 77)
 ( 81)
 ( 102)

 Total expense
 $
 $
 $
 $
 $
 $

 1Included in "Other income" on Edison International's and SCE's consolidated income statements. For further details, see Note 16.
 Other changes in pension plan assets and benefit obligations recognized in other comprehensive income:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Net (gain) loss
 $
 ( 9)
 $
 $
 ( 45)
 $
 ( 2)
 $
 $
 ( 24)

 Settlement charges
 —
 —
 ( 4)
 —
 —
 ( 4)

 Amortization of net gain
 ( 4)
 ( 2)
 ( 8)
 ( 2)
 ( 2)
 ( 5)

 Total (gain) loss recognized in other comprehensive income
 ( 13)
 ( 57)
 ( 4)
 ( 33)

 Total recognized in expense and other comprehensive income
 $
 $
 $
 ( 38)
 $
 $
 $
 ( 17)

 In accordance with authoritative guidance on rate-regulated enterprises, SCE records amortization of net gains and losses into regulatory assets and liabilities instead of charges and credits to other comprehensive income for the portion of SCE's postretirement benefit plans that are recoverable in utility rates.
 Edison International and SCE used the following weighted average assumptions to determine pension expense:

 2024
 2023
 2022

 Discount rate
 5.04
 %
 5.36
 %
 2.75
 %

 Rate of compensation increase
 4.00
 %
 4.00
 %
 4.00
 %

 Expected long-term return on plan assets
 6.75
 %
 6.50
 %
 5.50
 %

 Interest crediting rate for cash balance account1:

 Starting rate
 5.54
 %
 5.86
 %
 3.12
 %

 Ultimate rate
 5.54
 %
 5.86
 %
 4.50
 %

 Year ultimate rate is reached
 2024
 2023
 2026

 1Edison International and SCE were using a graduated assumption for interest crediting rate for cash balance account, where current interest rate gradually increased to an ultimate rate at a certain year. Starting 2023, Edison International and SCE changed to use single interest crediting rate assumption to determine the pension expense for cash balance account.

 The following benefit payments, which reflect service rendered and expected future service, are expected to be paid:

 Edison
International
 SCE

 2025
 $
 $

 2026

 2027

 2028

 2029

 2030 – 2034
 1,496
 1,370

 PBOP(s)
 Employees hired prior to December 31, 2017 who retire at or after age 55 with at least 10 years of service may be eligible for postretirement healthcare benefits. Eligibility for a company contribution toward the cost of these benefits in retirement depends on a number of factors, including the employee's years of service, age, hire date, and retirement date. Employees hired on or after December 31, 2017 are no longer eligible for retiree healthcare benefits. In lieu of those benefits, Edison International will provide a health reimbursement account of $ 200 per month available only after meeting certain age and service year requirements. Under the terms of the Edison International Welfare Benefit Plan ("PBOP Plan"), each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of PBOP Plan benefits with respect to its employees and former employees that exceed the participants' share of contributions. A participating employer may terminate the PBOP Plan benefits with respect to its employees and former employees, as may SCE (as PBOP Plan sponsor), and, accordingly, the participants' PBOP Plan benefits are not vested benefits.
 There are no expected contributions for PBOP benefits for the year ended December 31, 2025. Annual contributions related to SCE employees made to SCE plans are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the total annual expense for these plans.
 SCE has three voluntary employees' beneficiary association trusts ("VEBA Trusts") that can only be used to pay for retiree health care benefits of SCE and its subsidiaries. Once funded into the VEBA Trusts, neither SCE nor Edison International can subsequently recover the remaining amounts in the VEBA Trusts. Participants of the PBOP Plan do not have a beneficial interest in the VEBA Trusts. The VEBA Trust assets are sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's other postretirement benefits are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, the funded status is offset by a regulatory liability.

 Information on PBOP Plan assets and benefit obligations is shown below:

 SCE

 2024
 2023
 2024
 2023

 Change in benefit obligation

 Benefit obligation at beginning of year
 $
 $
 1,331
 $
 $
 1,323

 Service cost

 Interest cost

 Change in plan provisions
 —
 —

 Actuarial gain
 ( 34)
 ( 567)
 ( 34)
 ( 563)

 Plan participants' contributions

 Benefits paid
 ( 99)
 ( 106)
 ( 99)
 ( 106)

 Benefit obligation at end of year
 $
 $
 $
 $

 Change in plan assets

 Fair value of plan assets at beginning of year
 $
 2,275
 $
 2,187
 $
 2,275
 $
 2,187

 Actual return on assets

 Employer contributions

 Plan participants' contributions

 Benefits paid
 ( 99)
 ( 106)
 ( 99)
 ( 106)

 Fair value of plan assets at end of year
 2,281
 2,275
 2,281
 2,275

 Overfunded status at end of year
 $
 1,540
 $
 1,502
 $
 1,544
 $
 1,506

 Amounts recognized in the consolidated balance sheets consist of:

 Long-term assets
 $
 1,544
 $
 1,506
 $
 1,544
 $
 1,506

 Current liabilities
 ( 1)
 —
 —
 —

 Long-term liabilities
 ( 3)
 ( 4)
 —
 —

 $
 1,540
 $
 1,502
 $
 1,544
 $
 1,506

 Amounts recognized in accumulated other comprehensive loss consist of:

 Net gain
 $
 ( 4)
 $
 ( 5)
 $
 —
 $
 —

 Amounts recognized as a regulatory liability
 ( 1,544)
 ( 1,505)
 ( 1,544)
 ( 1,505)

 Weighted average assumptions used to determine obligations at end of year:

 Discount rate
 5.60
 %
 5.06
 %
 5.60
 %
 5.06
 %

 Assumed health care cost trend rates:

 Rate assumed for following year
 6.25
 %
 6.50
 %
 6.25
 %
 6.50
 %

 Ultimate rate
 5.00
 %
 5.00
 %
 5.00
 %
 5.00
 %

 Year ultimate rate reached
 2029
 2029
 2029
 2029

 For both Edison International and SCE, the 2024 actuarial gains are primarily related to $ 41 million in gains from the change in discount rate. For Edison International and SCE, the 2023 actuarial gains are primarily related to $ 553 million and $ 550 million in gains from the change in postretirement medical carrier and retiree medical delivery mechanism effective in 2024, respectively.

 Net periodic PBOP expense components are:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Service cost
 $
 $
 $
 $
 $
 $

 Non-service cost (benefit)

 Interest cost

 Expected return on plan assets
 ( 113)
 ( 97)
 ( 113)
 ( 97)

 Amortization of prior service cost
 ( 1)
 ( 1)
 ( 2)
 ( 1)
 ( 1)
 ( 2)

 Amortization of net gain
 ( 95)
 ( 50)
 ( 45)
 ( 95)
 ( 50)
 ( 45)

 Regulatory adjustment

 Total non-service benefit1

 ( 14)
 ( 20)
 ( 33)
 ( 14)
 ( 20)
 ( 34)

 Total expense
 $
 —
 $
 —
 $
 $
 —
 $
 —
 $
 —

 1Included in "Other income" on Edison International's and SCE's consolidated income statements. For further details, see Note 16.
 In accordance with authoritative guidance on rate-regulated enterprises, SCE records amortization of net gains and losses to regulatory assets and liabilities instead of charges and credits to other comprehensive income (loss) for the portion of SCE's postretirement benefit plans that are recoverable in utility rates.
 Edison International and SCE used the following weighted average assumptions to determine PBOP expense:

 2024
 2023
 2022

 Discount rate
 5.06 %
 5.43 %
 2.95 %

 Expected long-term return on plan assets
 4.88 %
 5.00 %
 3.50 %

 Assumed health care cost trend rates:

 Current year
 6.50 %
 6.75 %
 6.25 %

 Ultimate rate
 5.00 %
 5.00 %
 5.00 %

 Year ultimate rate reached
 2029
 2029
 2029

 The following benefit payments (net of plan participants' contributions) are expected to be paid:

 Edison
International
 SCE

 2025
 $
 $

 2026

 2027

 2028

 2029

 2030 – 2034

 Plan Assets
 Description of Pension and Postretirement Benefits Other than Pensions Investment Strategies
 The investment of plan assets is overseen by a fiduciary investment committee. Plan assets are invested using a combination of asset classes and may have active and passive investment strategies within asset classes. Target allocations for 2024 pension plan assets were 17.3 % for U.S. equities, 9.7 % for non-U.S. equities, 55 % for fixed income and 18 % for opportunistic and/or alternative investments. Target allocations for 2024 PBOP plan assets (except for Represented VEBA which is 95 % for fixed income and 5 % for U.S. and non-U.S. equities) are 29 % for U.S. and non-U.S. equities, 65 % for fixed income and 6 % for opportunistic and/or alternative investments. Edison International employs multiple investment management firms. Investment managers within each asset class cover a range of investment styles and approaches. Risk is managed through diversification among multiple asset classes, managers, styles and securities. Plan asset classes and

 individual manager performances are measured against targets. Edison International also monitors the stability of its investment managers' organizations.
 Allowable investment types under CPUC investment guidelines include:
 • United States equities: common and preferred stocks of large, medium, and small companies which are predominantly United States-based.
 • Non-United States equities: equity securities issued by companies domiciled outside the United States and in depository receipts which represent ownership of securities of non-United States companies.
 • Fixed income: fixed income securities issued or guaranteed by the United States government, non-United States governments, government agencies and instrumentalities including municipal bonds, mortgage backed securities and corporate debt obligations. A portion of the fixed income positions may be held in debt securities that are below investment grade.
 • Opportunistic, alternative and other investments: Opportunistic investments in short to intermediate term market opportunities. Investments may have fixed income and/or equity characteristics and may be either liquid or illiquid. Alternative investments are limited partnerships that invest in non-publicly traded entities. Other investments are diversified among multiple asset classes such as global equity, fixed income currency and commodities markets. Investments are made in liquid or illiquid instruments within and across markets. The investment returns are expected to approximate the plans' expected investment returns.
 Asset class portfolio weights are permitted to range within plus or minus 5 %. Where approved by the fiduciary investment committee, futures contracts are used for portfolio rebalancing and to reallocate portfolio cash positions. Where authorized, a few of the plans' investment managers employ limited use of derivatives, including futures contracts, options, options on futures and interest rate swaps in place of direct investment in securities to gain efficient exposure to markets. Derivatives are not used to leverage the plans or any portfolios.
 Determination of the Expected Long-Term Rate of Return on Assets
 The overall expected long-term rate of return on assets assumption is based on the long-term target asset allocation for plan assets and capital markets return forecasts for asset classes employed. A portion of the PBOP trust asset returns is subject to taxation, so the expected long-term rate of return for these assets is determined on an after-tax basis.
 Capital Markets Return Forecasts
 Edison International's capital markets return forecast methodologies primarily use a combination of historical market data, current market conditions, proprietary forecasting expertise, complex models to develop asset class return forecasts, and a building block approach. The forecasts are developed using variables such as real risk-free interest, inflation and asset class specific risk premiums. For equities, the risk premium is based on an implied average equity risk premium of 4 % over cash. The forecasted return on private equity and opportunistic investments are estimated at a 3 % premium above public equity, reflecting a premium for higher volatility and lower liquidity. For fixed income, the risk premium is based on a comprehensive modeling of credit spreads.
 Fair Value of Plan Assets
 The PBOP Plan and the Southern California Edison Company Retirement Plan Trust assets include investments in equity securities, U.S. treasury securities, other fixed-income securities, common/collective funds, mutual funds, other investment entities, foreign exchange and interest rate contracts, and partnership/joint ventures. Equity securities, U.S. treasury securities, and mutual and money market funds are classified as Level 1 as fair value is determined by observable, unadjusted quoted market prices in active or highly liquid and transparent markets. The fair value of the underlying investments in equity mutual funds are based on stock-exchange prices. The fair value of the underlying investments in fixed-income mutual funds and other fixed income securities including municipal bonds are based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers, and relevant credit information. Foreign exchange and interest rate contracts are classified as Level 2 because the values are based on observable prices but are not traded on an exchange. Futures contracts trade on an exchange and therefore are classified as Level 1. No investment is classified as Level 3 as of December 31, 2024 and 2023. Common/collective funds and partnerships are measured at fair value using the net asset value per share ("NAV") and have not been classified in the fair value hierarchy. Other investment entities are valued similarly to common/collective funds and are therefore classified as NAV. The Level 1 registered investment companies are either mutual or money market funds. The remaining funds in this category are readily redeemable and classified as NAV and are discussed further in the below pension plan trust investments table's note 8.

 Edison International reviews the process/procedures of both the pricing services and the trustee to gain an understanding of the inputs/assumptions and valuation techniques used to price each asset type/class. The trustee and Edison International's validation procedures for pension and PBOP equity and fixed income securities are the same as the nuclear decommissioning trusts. For further discussion, see Note 4. The values of Level 1 mutual and money market funds are publicly quoted. The trustees obtain the values of common/collective and other investment funds from the fund managers. The values of partnerships are based on partnership valuation statements updated for cash flows. SCE's investment managers corroborate the trustee fair values.
 Pension Plan
 The following table sets forth the investments for Edison International and SCE that were accounted for at fair value as of December 31, 2024 and 2023, respectively, by asset class and level within the fair value hierarchy:

 NAV1

 Total

 U.S. government and agency securities2

 $
 $
 $
 —
 $

 Corporate stocks3

 —

 Corporate bonds4

 —
 1,084
 —
 1,084

 Common/collective funds5

 —
 —

 Partnerships/joint ventures6

 —
 —

 Other investment entities7

 —
 —

 Registered investment companies8

 —

 Interest-bearing cash
 —
 —

 Other
 —

 Total
 $
 $
 1,498
 $
 1,540
 $
 3,682

 Receivables and payables, net
 ( 74)

 Combined net plan assets available for benefits
 3,608

 SCE's share of net plan assets
 $
 3,416

 NAV1

 Total

 U.S. government and agency securities2

 $
 $
 $
 —
 $

 Corporate stocks3

 —

 Corporate bonds4

 —
 1,057
 —
 1,057

 Common/collective funds5

 —
 —

 Partnerships/joint ventures6

 —
 —

 Other investment entities7

 —
 —

 Registered investment companies8

 —

 Interest-bearing cash
 —
 —

 Other
 —

 Total
 $
 $
 1,460
 $
 1,460
 $
 3,574

 Receivables and payables, net

 Combined net plan assets available for benefits
 3,609

 SCE's share of net plan assets
 $
 3,415

 1These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
 2Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal National Mortgage Association and the Federal Home Loan Mortgage Corporation.

 3Corporate stocks are diversified. At December 31, 2024 and 2023, respectively, performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 33 % and 36 %) and Morgan Stanley Capital International (MSCI) index ( 67 % and 64 %).
 4Corporate bonds are diversified. At December 31, 2024 and 2023, respectively, this category includes $ 77 million and $ 78 million for collateralized mortgage obligations and other asset backed securities.
 5The common/collective assets are invested in equity index funds that seek to track performance of the Standard and Poor's 500 Index ( 38 % and 41 % at December 31, 2024 and 2023). In addition, at December 31, 2024 and 2023, respectively, 38 % and 40 % of the assets in this category are in index funds which seek to track performance in the MSCI All Country World Index ex-US and 19 % and 16 % of this category are in a non-index U.S. equity fund, which is actively managed.
 6At December 31, 2024 and 2023, respectively, 69 % and 74 % are invested in private equity funds with investment strategies that include branded consumer products and clean technology companies, 16 % and 17 % are invested in ABS including distressed mortgages and commercial and residential loans, 9 % and zero are invested in fixed income securities, and 5 % are invested in a broad range of financial assets in all global markets at both December 31, 2024 and 2023.
 7At December 31, 2024 and 2023, respectively, 70 % and 68 % are invested in domestic mortgage backed securities and 30 % and 32 % in high yield debt securities.
 8 At December 31, 2024 and 2023, respectively, 56 % and 57 % are invested in Level 1 corporate bond funds, 10 % and 13 % in a fixed income fund used for cash management, and 34 % and 28 % in a US equity fund.
 At December 31, 2024 and 2023, respectively, approximately 64 % and 62 % of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
 Postretirement Benefits Other than Pensions
 The following table sets forth the VEBA Trust assets for Edison International and SCE that were accounted for at fair value as of December 31, 2024 and 2023, respectively, by asset class and level within the fair value hierarchy:

 NAV1

 Total

 U.S. government and agency securities2

 $
 $
 $
 —
 $

 Corporate stocks3

 —

 Corporate notes and bonds4

 —
 1,126
 —
 1,126

 Common/collective funds5

 —
 —

 Partnerships6

 —
 —

 Registered investment companies7

 —
 —

 Interest bearing cash
 —
 —

 Other8

 —
 —

 Total
 $
 $
 1,319
 $
 $
 2,295

 Receivables and payables, net
 ( 14)

 Net plan assets available for benefits
 $
 2,281

 NAV1

 Total

 U.S. government and agency securities2

 $
 $
 $
 —
 $

 Corporate stocks3

 —

 Corporate notes and bonds4

 —
 1,064
 —
 1,064

 Common/collective funds5

 —
 —

 Partnerships6

 —
 —

 Registered investment companies7

 —
 —

 Interest bearing cash
 —
 —

 Other8

 —

 Total
 $
 $
 1,249
 $
 $
 2,298

 Receivables and payables, net
 ( 23)

 Net plan assets available for benefits
 $
 2,275

 1These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
 2Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal Home Loan Mortgage Corporation and the Federal National Mortgage Association.
 3Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 78 % and 74 % at December 31, 2024 and 2023, respectively) and the MSCI All Country World Index ( 22 % and 26 % at December 31, 2024 and 2023, respectively).
 4Corporate notes and bonds are diversified and include approximately $ 343 million and $ 237 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2024 and 2023, respectively.
 5At December 31, 2024 and 2023, respectively, 47 % and 45 % of the common/collective assets are invested in index funds which seek to track performance in the MSCI All Country World Investable Market Index, 41 % and 40 % are invested in a non-index U.S. equity fund which is actively managed. The remaining assets in this category are primarily invested in emerging market fund and fixed income funds.
 6At December 31, 2024 and 2023, respectively, 71 % and 65 % of the partnerships are invested in private equity and venture capital funds. Investment strategies for these funds include branded consumer products, clean and information technology and healthcare. Of the remaining partnerships category, 22 % and 28 % are invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks; 7 % are invested in a broad range of financial assets in all global markets at both December 31, 2024 and 2023.
 7At December 31, 2024 and 2023, respectively, registered investment companies were primarily invested in a money market fund ( 73 % and 70 %) and exchange rate traded funds which seek to track performance of MSCI Emerging Market Index, Russell 2000 Index and international small cap equities ( 27 % and 30 %).
 8Other includes $ 52 million and $ 58 million of municipal securities at December 31, 2024 and 2023, respectively.
 At both December 31, 2024 and 2023, approximately 78 % of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
 Stock-Based Compensation
 Edison International maintains a shareholder-approved incentive plan (the "2007 Performance Incentive Plan") that includes stock-based compensation. The maximum number of shares of Edison International's common stock authorized to be issued or transferred pursuant to awards under the 2007 Performance Incentive Plan, as amended, is approximately 71 million shares. As of December 31, 2024, Edison International had approximately 13 million shares remaining available for new award grants under its stock-based compensation plans.

 The following table summarizes total expense and tax benefits associated with stock-based compensation:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Stock-based compensation expense1:

 Stock options
 $
 $
 $
 $
 $
 $

 Performance shares

 Restricted stock units

 Other
 —
 —
 —

 Total stock-based compensation expense
 $
 $
 $
 $
 $
 $

 Income tax benefits related to stock-based compensation expense
 $
 $
 $
 $
 $
 $

 1Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income.
 Stock Options
 Under the 2007 Performance Incentive Plan, Edison International has granted stock options at exercise prices equal to the closing price at the grant date. Edison International may grant stock options and other awards related to, or with a value derived from, its common stock to directors and certain employees. Options generally expire 10 years after the grant date and vest over a period of three or four years of continuous service in equal annual increments, except for awards granted to retirement-eligible participants, which vest on an accelerated basis.
 The fair value for each option granted was determined as of the grant date using the Black-Scholes option-pricing model. The Black-Scholes option-pricing model requires various assumptions noted in the following table:

 2024
 2023
 2022

 Expected terms (in years)
 4.7
 4.8
 5.0

 Risk-free interest rate
 3.7 % - 4.5 %

 3.6 % - 4.7 %

 1.6 % - 4.1 %

 Expected dividend yield
 3.6 % - 4.7 %

 4.2 % - 4.7 %

 4.0 % - 5.0 %

 Weighted average expected dividend yield
 4.7 %
 4.2 %
 4.0 %

 Expected volatility
 23.6 % - 30.4 %

 29.0 % - 29.6 %

 27.8 % - 28.6 %

 Weighted average volatility
 30.3 %
 29.1 %
 27.8 %

 The expected term represents the period of time for which the options are expected to be outstanding and is primarily based on historical exercise and post-vesting cancellation experience and stock price history. The risk-free interest rate for periods within the contractual life of the option is based on a zero-coupon U.S. Treasury STRIPS (separate trading of registered interest and principal of securities) whose maturity corresponds to the option's expected term on the measurement date. Expected volatility is based on the historical volatility of Edison International's common stock for the length of the option's expected term. The volatility period used was 56 months, 58 months, and 60 months at December 31, 2024, 2023, and 2022, respectively.

 The following is a summary of the status of Edison International's stock options:

 Exercise
Price
 Remaining
Contractual
Term (years)
 Aggregate
Intrinsic Value

 Outstanding at December 31, 2023
 11,418,243
 $
 64.30

 749,968
 66.70

 Forfeited or expired
 ( 107,158)
 71.89

 Exercised1

 ( 3,417,478)
 64.49

 Outstanding at December 31, 2024
 8,643,575
 64.33
 5.01

 Exercisable and expected to vest at December 31, 2024
 8,438,864
 64.40
 4.95
 $

 Exercisable at December 31, 2024
 6,651,227
 $
 64.79
 4.19
 $

 SCE:

 Outstanding at December 31, 2023
 5,192,275
 $
 64.22

 390,760
 66.82

 Forfeited or expired
 ( 98,077)
 71.44

 Exercised1

 ( 1,892,980)
 64.49

 Affiliate transfers, net
 14,472
 64.22

 Outstanding at December 31, 2024
 3,606,450
 64.18
 5.27

 Exercisable and expected to vest at December 31,2024
 3,508,129
 64.25
 5.21
 $

 Exercisable at December 31, 2024
 2,609,173
 $
 64.66
 4.33
 $

 1Edison International and SCE recognized tax benefits of $ 13 million and $ 7 million, respectively, from stock options exercised in 2024.
 At December 31, 2024, total unrecognized compensation cost related to stock options and the weighted average period the cost is expected to be recognized are as follows:

 SCE

 Unrecognized compensation cost, net of expected forfeitures (in millions)
 $
 $

 Weighted average period (in years)
 1.3
 1.3

 The following is a summary of supplemental data on stock options:

 SCE

 (in millions, except per award amounts)
 2024
 2023
 2022
 2024
 2023
 2022

 Weighted average grant date fair value per option granted
 $
 13.32
 $
 12.69
 $
 9.92
 $
 13.36
 $
 12.71
 $
 9.92

 Fair value of options vested

 Value of options exercised

 Performance Shares
 A target number of contingent performance shares were awarded to executives in 2024, 2023, and 2022 and vest as of December 31, 2026, 2025, and 2024, respectively. The vesting of the grants is dependent upon market and financial performance and service conditions as defined in the grants for each of the years. The number of performance shares earned from each year's grants could range from zero to twice the target number (plus additional units credited as dividend equivalents).
 The fair value of market condition performance shares is determined using a Monte Carlo simulation valuation model for the total shareholder return. The fair value of financial performance condition performance shares is determined (i) at grant

 as the target number of shares (which Edison International determined to be the probable outcome) valued at the closing price on the grant date of Edison International common stock and (ii) subsequently using Edison International's earnings per share compared to pre-established targets.
 The following is a summary of the status of Edison International's nonvested performance shares:

 Equity Awards

 Nonvested at December 31, 2023
 496,841
 $
 71.93

 276,838
 72.21

 Forfeited
 ( 5,872)
 72.57

 Vested
 ( 249,287)
 67.90

 Nonvested at December 31, 2024
 518,520
 $
 74.01

 SCE:

 Nonvested at December 31, 2023
 249,091
 $
 71.99

 144,339
 72.37

 Forfeited
 ( 5,282)
 72.23

 Vested
 ( 123,197)
 67.73

 Affiliate transfers, net
 71.99

 Nonvested at December 31, 2024
 264,974
 $
 74.17

 Restricted Stock Units
 Restricted stock units were awarded to executives in 2024, 2023, and 2022 and vest and become payable on January 4, 2027, January 2, 2026, and January 2, 2025, respectively. Each restricted stock unit awarded includes a dividend equivalent feature and is a contractual right to receive one share of Edison International common stock, if vesting requirements are satisfied. The vesting of Edison International's restricted stock units is dependent upon continuous service through the end of the vesting period, except for awards granted to retirement-eligible participants, which vest on an accelerated basis.
 The following is a summary of the status of Edison International's nonvested restricted stock units:

 SCE

Grant Date
Grant Date

 Nonvested at December 31, 2023
 892,412
 $
 61.19
 645,549
 $
 61.17

 325,501
 66.88
 233,112
 66.88

 Forfeited
 ( 22,886)
 65.24
 ( 18,908)
 65.34

 Vested
 ( 318,579)
 55.71
 ( 238,921)
 55.89

 Affiliate transfers, net
 —
 —
 ( 105)
 61.17

 Nonvested at December 31, 2024
 876,448
 $
 65.19
 620,727
 $
 65.22

 The fair value for each restricted stock unit awarded is determined as the closing price of Edison International common stock on the grant date.

 Note 10. Investments
 Nuclear Decommissioning Trusts
 Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts.
 The following table sets forth amortized cost and fair value of the trust investments (see Note 4 for a discussion on fair value of the trust investments):

 Amortized Costs
 Fair Values

 Longest Maturity Dates
2024
2023
2024
2023

 Municipal bonds
 2067
 $
 $
 $
 $

 Government and agency securities
 2074
 1,201
 1,072
 1,341
 1,186

 Corporate bonds
 2072

 Short-term investments and receivables/payables1

 One-year

 Total debt securities and other
 2,428
 2,233
 2,655
 2,515

 Equity securities
 1,631
 1,658

 Total2

 $
 4,286
 $
 4,173

 1Short-term investments include $ 18 million and $ 38 million of repurchase agreements payable by financial institutions which earn interest, were both fully secured by U.S. Treasury securities and mature by January 2, 2025 and January 2, 2024 as of December 31, 2024 and 2023, respectively.
 2 Represents amounts before reduction for deferred tax liabilities on net unrealized gains of $ 373 million and $ 380 million as of December 31, 2024 and 2023, respectively.
 Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability. Unrealized holding gains, net of losses, were $ 1.7 billion and $ 1.8 billion at December 31, 2024 and 2023, respectively.
 The following table summarizes the gains and losses for the trust investments:

 2024
 2023
 2022

 Gross realized gains
 $
 $
 $

 Gross realized losses
 ( 24)
 ( 73)
 ( 127)

 Net unrealized (losses) gains for equity securities
 ( 19)
 ( 369)

 Due to regulatory mechanisms, changes in the assets of the trusts from income or loss items do not materially affect earnings.

 Note 11. Regulatory Assets and Liabilities
 Included in SCE's regulatory assets and liabilities are regulatory balancing accounts. CPUC-authorized balancing account mechanisms require SCE to refund or recover any differences between forecasted and actual costs. The CPUC has authorized balancing accounts for specified costs or programs such as fuel, purchased power, demand-side management programs, wildfire related costs, nuclear decommissioning and public purpose programs. Certain of these balancing accounts include a return on rate base of 7.87 % and 7.44 % in 2024 and 2023, respectively. The CPUC authorizes the use of a balancing account to recover from or refund to customers differences in revenue resulting from actual and forecasted electricity sales.
 Amounts included in regulatory assets and liabilities are generally recorded with corresponding offsets to the applicable income statement accounts.

 Regulatory Assets
 SCE's regulatory assets included on the consolidated balance sheets are:

 2024
 2023

 Current:

 Regulatory balancing and memorandum accounts
 $
 2,723
 $
 2,502

 Other

 Total current
 2,748
 2,524

 Long-term:

 5,982
 5,533

 Unamortized investments, net of accumulated amortization

 Unamortized losses on reacquired debt

 Regulatory balancing and memorandum accounts
 1,257

 Environmental remediation

 Recovery assets
 1,512
 1,558

 Other

 Total long-term
 8,886
 8,897

 Total regulatory assets
 $
 11,634
 $
 11,421

 In accordance with the accounting standards applicable to rate-regulated enterprises, SCE defers costs as regulatory assets that are probable of future recovery from customers and has recorded regulatory assets for these incremental costs at December 31, 2024. While SCE believes such costs are probable of future recovery, there is no assurance that SCE will collect all amounts currently deferred as regulatory assets.
 SCE's regulatory assets related to deferred income taxes represent tax benefits passed through to customers. The CPUC requires SCE to flow through certain deferred income tax benefits to customers by reducing electricity rates, thereby deferring recovery of such amounts to future periods. Based on current regulatory ratemaking and income tax laws, SCE expects to recover its regulatory assets related to deferred income taxes over the life of the assets that give rise to the accumulated deferred income taxes, approximately from 1 to 60 years. For further information, see Note 8.
 SCE has long-term unamortized investments which include nuclear assets related to Palo Verde and the beyond the meter program. Nuclear assets related to Palo Verde and the beyond the meter program are expected to be recovered by 2046 and 2031, respectively, and both earned returns of 7.87 % and 7.44 % in 2024 and 2023, respectively.
 SCE's net regulatory asset related to its unamortized losses on reacquired debt will be recovered over the original amortization period of the reacquired debt over periods ranging from 10 to 40 years or the life of the new issuance if the debt is refunded or refinanced.
 SCE's regulatory assets related to environmental remediation represent a portion of the costs incurred at certain sites that SCE is allowed to recover through customer rates. See "Environmental Remediation" discussed in Note 12.
 Recovery assets represent the balance associated with the Recovery Property and prudently incurred financing costs securitized with issuance of the associated bond. The recovery period is until 2047, when the bonds and interest are paid in full. For further details, see Note 3.

 Regulatory Liabilities
 SCE's regulatory liabilities included on the consolidated balance sheets are:

 2024
 2023

 Current:

 Regulatory balancing and memorandum accounts
 $
 1,144
 $

 Energy derivatives

 Other

 Total current
 1,347

 Long-term:

 Costs of removal
 2,520
 2,635

 2,163
 2,211

 Recoveries in excess of ARO liabilities
 1,748
 1,498

 Regulatory balancing and memorandum accounts
 2,023
 1,395

 Pension and other postretirement benefits
 1,690
 1,664

 Other

 Total long-term
 10,159
 9,420

 Total regulatory liabilities
 $
 11,506
 $
 10,183

 SCE's regulatory liabilities related to energy derivatives are primarily an offset to unrealized gains on derivatives.
 SCE's regulatory liabilities related to costs of removal represent differences between asset removal costs recorded and amounts collected in rates for those costs.
 SCE's regulatory liabilities include excess deferred income taxes resulting from statutory income tax rate changes. The regulatory liabilities are generally expected to be refunded to customers over the lives of the assets and liabilities that gave rise to the deferred income taxes.
 SCE's regulatory liabilities related to recoveries in excess of ARO liabilities represent the cumulative differences between ARO obligations and amounts collected in rates primarily for the decommissioning of SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 10 for further discussion.
 SCE's regulatory liabilities related to pension and other post-retirement plans represent the net overfunded status of the plans. This amount is expected to be amortized over the expected future service of the employees (subject to regulatory adjustment) or refunded to ratepayers at the termination or completion of the plan. See "Pension Plans and Postretirement Benefits Other than Pensions" discussion in Note 9.
 Net Regulatory Balancing and Memorandum Accounts
 Balancing accounts track amounts that the CPUC or FERC have authorized for recovery. Balancing account over and under collections represent differences between cash collected in current rates for specified forecasted costs and such costs that are actually incurred. Undercollections are recorded as regulatory balancing account assets. Overcollections are recorded as regulatory balancing account liabilities. With some exceptions, SCE seeks to adjust rates on an annual basis or at other designated times to recover or refund the balances recorded in its balancing accounts. Memorandum accounts are authorized to track costs for potential future recovery.
 Regulatory balancing and memorandum accounts that SCE does not expect to collect or refund in the next 12 months are reflected in the long-term section of the consolidated balance sheets. Regulatory balancing and memorandum accounts that do not have the right of offset are presented gross in the consolidated balance sheets. Under and over collections in balancing accounts and amounts recorded in memorandum accounts typically accrue interest based on a three-month commercial paper rate published by the Federal Reserve.
 The following table summarizes the significant components of regulatory balancing and memorandum accounts included in the above tables of regulatory assets and liabilities:

 2024
 2023

 Asset (liability)

 Energy procurement related costs
 $
 ( 97)
 $

 Public purpose and energy efficiency
 ( 1,708)
 ( 1,736)

 GRC related balancing accounts1

 1,361

 FERC related balancing accounts
 ( 211)

 Wildfire risk mitigation and insurance2

 1,169

 Wildfire and drought restoration3

 Tax accounting memorandum account
 ( 40)

 Other

 Assets, net of liabilities
 $
 $
 1,660

 1The GRC related balancing accounts primarily consist of the base revenue requirement balancing account ("BRRBA"), the vegetation management balancing account ("VMBA"), the Wildfire Risk Mitigation balancing account ("WRMBA") and the risk management balancing account ("RMBA").
 The 2021 GRC decision approved the establishment of the VMBA to track vegetation management expenses up to 115 % of amounts authorized, the WRMBA to track the costs of SCE's Wildfire Covered Conductor Program up to 110 % of amounts authorized and the RMBA to track the authorized costs of wildfire insurance. If spending is less than authorized, SCE will refund those amounts to customers. If spending is within the specified threshold, if any, for each balancing account, SCE will recover those costs from customers. Amounts above the specified threshold, or above amounts authorized if a higher threshold was not established, for each balancing account may be eligible for deferral to wildfire risk mitigation and insurance accounts.
 2The wildfire risk mitigation and insurance regulatory assets represent wildfire-related costs that are probable of future recovery from customers, subject to a reasonableness review. The Fire Hazard Prevention Memorandum Account was used to track costs related to fire safety and to implement fire prevention corrective action measures in extreme and very high fire threat areas. The Wildfire Expense Memorandum Account ("WEMA") is used to track incremental wildfire insurance costs and uninsured wildfire-related financing, legal and claims costs related to the Other Wildfire Events that SCE believes are probable of recovery. See Note 12 for further details. The Wildfire Mitigation Plan Memorandum Account is used to track costs incurred to implement SCE's wildfire mitigation plan that are not currently reflected in SCE's revenue requirements. The Fire Risk Mitigation Memorandum Account is used to track costs related to the reduction of fire risk that are incremental to costs approved for recovery in SCE's GRCs that are not tracked in any other wildfire-related memorandum account. The balance also includes vegetation management spending in excess of the 115 % threshold for the VMBA described above.
 3The wildfire and drought restoration regulatory assets represent restoration costs that are recorded in a Catastrophic Event Memorandum Account.

 Note 12. Commitments and Contingencies
 Power Purchase Agreements
 SCE entered into various agreements to purchase power, electric capacity and other energy products. At December 31, 2024, the undiscounted future expected minimum payments for the SCE PPAs (primarily related to renewable energy contracts), which were approved by the CPUC and met other critical contract provisions (including completion of major milestones for construction), were as follows:

 Total

 2025
 $
 2,986

 2026
 3,139

 2027
 2,704

 2028
 2,423

 2029
 2,421

 Thereafter
 16,493

 Total future commitments1

 $
 30,166

 1Certain power purchase agreements are treated as operating leases. For further discussion, see Note 13. Includes long-term lease contracts commencing in 2024 with total future minimum lease payments of $ 57 million.
 Additionally, as of December 31, 2024, SCE has executed contracts that have not met the critical contract provisions that would increase contractual obligations by $ 25 million in 2025, $ 140 million in 2026, $ 274 million in 2027, $ 381 million in 2028, $ 450 million in 2029 and $ 5,370 million thereafter, if all critical contract provisions are completed.
 Costs incurred for PPAs were $ 4.0 billion in 2024, $ 4.5 billion in 2023 and $ 5.1 billion in 2022, which include costs associated with contracts with terms of less than one year.
 Other Commitments
 The following summarizes the estimated minimum future commitments for SCE's other commitments:

 2025
 2026
 2027
 2028
 2029
 Thereafter
 Total

 Other contractual obligations
 $
 $
 $
 $
 $
 $
 $

 Costs incurred for other commitments were $ 65 million in 2024, $ 60 million in 2023 and $ 58 million in 2022. Other commitments include fuel supply contracts for Palo Verde which require payment only if the fuel is made available for purchase. Also included are commitments related to maintaining reliability and expanding SCE's transmission and distribution system.
 The table above does not include asset retirement obligations, which are discussed in Note 1.
 Indemnities
 Edison International and SCE have agreed to provide indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, indemnities for specified environmental liabilities and income taxes or other contractual arrangements. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated.
 Contingencies
 In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax, and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business. Edison International and SCE believe the outcome of each of these other proceedings will not materially affect its financial position, results of operations and cash flows. Legal costs expected to be incurred by Edison International and SCE in connection with loss contingencies are expensed as incurred.

 Southern California Wildfires and Mudslides
 Unprecedented weather conditions in California due to climate change have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area, including as recently as January 2025.
 Numerous claims related to wildfire events have been initiated against SCE and Edison International. Edison International and SCE have, or may, incur material losses in connection with the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events that are described below, and the January 2025 Eaton Fire. Of the Other Wildfire Events described below, only the 2017 Creek Fire ignited prior to the adoption of AB 1054 in July 2019. SCE's equipment has been, and may further be, alleged to be associated with other wildfires that have originated in Southern California, and SCE's service area remains susceptible to additional wildfire activity.
 Liability Overview
 The extent of legal liability for wildfire-related damages in actions against utilities depends on a number of factors, including whether the utility substantially caused or contributed to the damages and whether parties seeking recovery of damages will be required to show negligence in addition to causation. California courts have previously found utilities to be strictly liable for property damage along with associated interest and attorneys' fees, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. If inverse condemnation is held to be inapplicable to SCE in connection with a wildfire, SCE still could be held liable for property damages and associated interest if the property damages were found to have been proximately caused by SCE's negligence. If SCE were to be found negligent, SCE could also be held liable for, among other things, fire suppression costs, business interruption losses, evacuation costs, clean-up costs, medical expenses, and personal injury/wrongful death claims, including claims for non-economic damages. Additionally, SCE could potentially be subject to fines and penalties for alleged violations of CPUC rules and state laws investigated in connection with the ignition of a wildfire.
 While investigations into the cause of a wildfire event are conducted by one or more fire agencies, fire agency findings do not determine legal causation of or assign legal liability for a wildfire event. Final determinations of legal causation and liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes, and settlements may be reached before determinations of legal liability are ever made. Even when investigations are still pending or legal liability is disputed, an assessment of likely outcomes, including through future settlement of disputed claims, may require estimated losses to be accrued under accounting standards. Each reporting period, management reviews its loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: estimates of known and expected claims by third parties based on currently available information, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, and prior experience litigating and settling wildfire litigation claims. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged and in estimating settlement outcomes.
 Estimates and Assumptions
 Edison International and SCE may incur a material loss in excess of amounts accrued in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events. Due to the number of uncertainties and possible outcomes related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events litigation, Edison International and SCE cannot estimate the upper end of the range of reasonably possible losses that may be incurred in connection with the 2017/2018 Wildfire/Mudslide Events or the Other Wildfire Events.
 Estimated losses for wildfire litigation are based on a number of assumptions and are subject to change as additional information becomes available. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged and uncertainty in estimating settlement outcomes. For instance, SCE receives additional information with respect to damages claimed as claims mediation and trial processes progress. Other factors that can cause actual losses incurred to be higher or lower than estimated include the ability to reach settlements and the outcomes of settlements reached through claims mediation processes, uncertainties related to the impact of outcomes of wildfire litigation against other parties and increasingly negative jury sentiments in general litigation, uncertainties related to the sufficiency of insurance held by plaintiffs, uncertainties related to litigation processes, including whether plaintiffs will ultimately pursue claims, uncertainty as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of wildfire events, the complexities associated with fires that merge, as applicable for the Thomas and Koenigstein Fires, and, for the Montecito Mudslides,

 whether inverse condemnation will be held applicable to SCE with respect to damages caused by the mudslides, and the uncertainty as to how these factors impact future settlements.
 Litigation
 Wildfires in SCE's service area in December 2017 and November 2018 caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers. The investigating government agencies, the Ventura County Fire Department ("VCFD") and CAL FIRE, have determined that the largest of the 2017 fires in SCE's service area originated on December 4, 2017, in the Anlauf Canyon area of Ventura County, followed shortly thereafter by a second fire that originated near Koenigstein Road in the City of Santa Paula. According to CAL FIRE, the Thomas and Koenigstein Fires, collectively, burned over 280,000 acres, destroyed or damaged an estimated 1,343 structures and resulted in two confirmed fatalities. The largest of the November 2018 fires in SCE's service area, the Woolsey Fire, originated in Ventura County. According to CAL FIRE, the Woolsey Fire burned almost 100,000 acres, destroyed an estimated 1,643 structures, damaged an estimated 364 structures and resulted in three confirmed fatalities. Four additional fatalities are alleged to have been associated with the Woolsey Fire.
 Multiple lawsuits related to the Thomas and Koenigstein Fires and the Woolsey Fire have been initiated against SCE and Edison International. Some of the Thomas and Koenigstein Fires lawsuits claim that SCE and Edison International have responsibility for the damages caused by debris flows and flooding in Montecito and surrounding areas in January 2018 based on a theory alleging that SCE has responsibility for the Thomas and/or Koenigstein Fires and further alleging that the Thomas and/or Koenigstein Fires proximately caused the Montecito Mudslides. According to Santa Barbara County initial reports, the Montecito Mudslides destroyed an estimated 135 structures, damaged an estimated 324 structures, and resulted in 21 confirmed fatalities, with two additional fatalities presumed but not officially confirmed.
 The lawsuits related to the 2017/2018 Wildfire/Mudslide Events naming SCE as a defendant have been filed by three categories of plaintiffs: individual plaintiffs, subrogation plaintiffs and public entity plaintiffs. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 20, 2025, in addition to the outstanding claims of approximately 290 individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding. SCE has settled all fire suppression claims and subrogation plaintiffs' claims related to the 2017/2018 Wildfire/Mudslide Events.
 In January 2019, SCE filed a cross-complaint against certain local public entities alleging that failures by these entities, such as failure to adequately plan for flood hazards and build and maintain adequate debris basins, roads, bridges and other channel crossings, among other things, caused, contributed to or exacerbated the losses that resulted from the Montecito Mudslides. Some of SCE's cross-claims are still outstanding.
 The litigation could take a number of years to be completely resolved because of the complexity of the matters and number of plaintiffs. As of February 20, 2025, SCE has entered into settlements with approximately 13,600 individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation. The statutes of limitations for individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events have expired. As of February 20, 2025, SCE has received demands for approximately 94 % and 100 % of outstanding individual plaintiff claims in the TKM litigation and Woolsey Fire litigation, respectively.
 In October 2021, SCE and the SED executed an agreement to resolve the SED's investigations into the 2017/2018 Wildfire/Mudslide Events and three other 2017 wildfires for, among other things, aggregate costs of $ 550 million. The $ 550 million in costs was composed of a $ 110 million fine to be paid to the State of California General Fund, $ 65 million of shareholder-funded safety measures, and an agreement by SCE to waive its right to seek cost recovery in CPUC-jurisdictional rates for $ 125 million and $ 250 million of third-party uninsured claims payments (and related financing costs) in the TKM litigation and the Woolsey Fire litigation, respectively. The SED Agreement provides that SCE may, on a permanent basis, exclude from its ratemaking capital structure any after-tax charges to equity or debt borrowed to finance costs incurred under the SED Agreement. The SED Agreement also imposes other obligations on SCE, including reporting requirements and safety-focused studies. SCE did not admit imprudence, negligence, or liability with respect to the 2017/2018 Wildfire/Mudslide Events in the SED Agreement.
 2017 Creek Fire
 The Creek Fire originated near Sylmar in Los Angeles County in December 2017 and burned approximately 16,000 acres, destroyed an estimated 123 structures, damaged an estimated 81 structures, and resulted in 3 civilian injuries. While the United States Forest Service's ("USFS") January 2018 report of investigation concluded that the Los Angeles Department of Water and Power ("LADWP") long-span transmission lines slapping together in high winds resulted in arcing and ignition of the fire, in August 2024, the USFS issued a supplemental report concluding that the fire was caused by SCE power lines. In 2023, the USFS dismissed its claim against LADWP and filed a claim against SCE to recover over $ 40 million for fire-suppression costs incurred by the USFS and environmental damage to U.S. lands. A trial in the USFS

 litigation is currently set for September 2025. Other than for the claims of 7 individual plaintiffs related to one property that were damaged by the Creek Fire, SCE has entered into settlements or settlements in principle on all claims filed by individual and subrogation plaintiffs who filed complaints against SCE related to the fire. A damages-only bench trial is currently set for June 2025 in one of the outstanding individual plaintiff cases. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. The SED is conducting an investigation with respect to the Creek Fire. SCE has accrued charges for potential losses relating to the Creek Fire.
 2019 Saddle Ridge Fire
 The "Saddle Ridge Fire," originated in Los Angeles County in October 2019 and burned approximately 9,000 acres, destroyed an estimated 19 structures, damaged an estimated 88 structures, and resulted in one fatality and injuries to eight fire fighters. In August 2023, SCE received a signed report of investigation from the LAFD, in which the LAFD stated with respect to the Saddle Ridge Fire that the cause of ignition was unintentional, the form of heat was undetermined, the item first ignited was undetermined and the material type first ignited was undetermined. The LAFD report noted that no other competent ignition sources other than SCE's transmission lines were found in the specific origin area of the Saddle Ridge Fire. The SED is conducting an investigation with respect to the Saddle Ridge Fire. There are currently no trials scheduled in the Saddle Ridge Fire litigation. Based on pending litigation and without considering insurance recoveries, it is reasonably possible that SCE will incur a material loss in connection with the Saddle Ridge Fire, but the range of reasonably possible losses that could be incurred cannot be estimated at this time. SCE has not determined that losses in connection with the Saddle Ridge Fire are probable and consequently has not accrued a charge for potential losses relating to the Saddle Ridge Fire.
 2020 Bobcat Fire
 The "Bobcat Fire" was reported in the vicinity of Cogswell Dam in Los Angeles County in September 2020. The USFS has reported that the Bobcat Fire burned approximately 116,000 acres in Los Angeles County, destroyed an estimated 87 homes, one commercial property and 83 minor structures, damaged an estimated 28 homes and 19 minor structures, and resulted in injuries to six firefighters. In addition, fire authorities have estimated suppression costs at approximately $ 80 million. An investigation into the cause of the Bobcat Fire was led by the USFS. In May 2023, SCE received a report of investigation from the USFS, in which the USFS finds that the Bobcat Fire was caused when an SCE electrical wire made contact with a tree limb. The SED has concluded its investigation of the Bobcat Fire and found no violations of its rules and regulations by SCE related to the Bobcat Fire. SCE has settled subrogation plaintiff claims and a claim brought by the United States of America against SCE and one of its contractors to recover fire-suppression costs, property and natural resource losses, and emergency response costs. Individual plaintiffs have also filed complaints against SCE related to the Bobcat Fire. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Bobcat Fire.
 2020 Silverado Fire
 The "Silverado Fire" originated in Orange County in October 2020 and burned over 12,000 acres. The Orange County Fire Authority ("OCFA"). OCFA jointly with CAL FIRE have reported that the Silverado Fire destroyed five structures, damaged nine other structures and resulted in two firefighter injuries. There were also four other structures damaged or destroyed. In addition, methane re-generation pipelines were destroyed and approximately 200 acres of avocado orchards were damaged in the fire. Fire authorities have estimated suppression costs at approximately $ 20 million. An investigation into the cause of the Silverado Fire was conducted by the OCFA and CAL FIRE. OCFA and CAL FIRE concluded in their October 2020 report of investigation that contact between an SCE conductor and a T-Mobile USA, Inc. ("T-Mobile") line resulted in ignition of the Silverado Fire. In 2024, SCE paid a fine of approximately $ 2 million imposed by the SED for failure to comply with maintenance requirements with respect to two conductors. Multiple lawsuits related to the Silverado Fire have been filed by individual and subrogation plaintiffs, CAL FIRE, T-Mobile, County of Orange and Cal OES naming SCE as a defendant. T-Mobile has also been named as a defendant and maintains a cross-complaint against SCE and Edison International. A trial in the Silverado Fire litigation has been set for May 2025. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Silverado Fire.
 2022 Coastal Fire
 The "Coastal Fire" originated in Orange County in May 2022 and burned approximately 200 acres. The Orange County Fire Authority ("OCFA") has reported that the Coastal Fire destroyed 20 residential structures and damaged 11 residential structures. Two firefighters also reportedly sustained minor injuries. In addition, fire authorities have estimated suppression costs at approximately $ 3 million. While SCE's investigation remains ongoing, SCE's information reflects that a SCE circuit in the area experienced an anomaly (a relay) approximately 2 minutes prior to the reported time of the fire. An

 investigation into the cause of the Coastal Fire was led by the OCFA. The OCFA has retained SCE equipment in connection with its investigation. In September 2024, SCE received a report of investigation from the OCFA, in which the OCFA finds that the Coastal Fire was unintentionally caused by sparks from overhead SCE electrical equipment igniting vegetation under the equipment. The SED is conducting an investigation with respect to the Coastal Fire. One damages only trial for one individual plaintiff household is currently scheduled for May 2025 in the Coastal Fire litigation. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Coastal Fire.
 2022 Fairview Fire
 The "Fairview Fire" originated in Riverside County in September 2022 and burned approximately 28,000 acres. CAL FIRE has reported that the Fairview Fire destroyed 22 residential structures, damaged five residential structures, and destroyed or damaged 17 minor structures. CAL FIRE also reported two civilian fatalities, one civilian injury and two injuries to responding fire personnel. In addition, fire authorities have estimated suppression costs at $ 39 million. While SCE's investigation remains ongoing, SCE's information reflects that a SCE circuit in the area experienced an anomaly (a relay) approximately 8 minutes prior to the reported start time of the fire. In November 2023, SCE received a report of investigation conducted by CAL FIRE, in which CAL FIRE finds that the Fairview Fire was caused when a sagging SCE electrical conductor came in contact with a communication line, causing sparks to fall and ignite surrounding vegetation. In July 2024, the SED issued a notice of violation alleging that SCE failed to comply with clearance requirements with respect to its electrical conductor. Jury trials for bellwether plaintiffs in the Fairview Fire litigation have been set for May 2025. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Fairview Fire.
 Settlement of Claims
 The following table presents settlements paid.

 Inception to December 31, 2024
 2024
 2023
 2022

 $
 9,454
 $
 $
 1,034
 $
 1,911

 Total
 $
 10,018
 $
 1,140
 $
 1,224
 $
 1,924

 Edison International and SCE has not admitted wrongdoing or liability as part of any settlements related to the 2017/2018 Wildfire/Mudslide Events or the Other Wildfire Events. SCE continues to explore reasonable settlement opportunities with plaintiffs in outstanding wildfire litigation.
 Loss Estimates
 The following table presents changes in estimated losses since December 31, 2023:

 Total

 Balance at December 31, 2023
 $
 $
 $
 1,398

 Increase in accrued estimated losses

 Amounts paid
 ( 779)
 ( 361)
 ( 1,140)

 Balance at December 31, 2024
 $
 $
 $
 1,001

 Edison International's and SCE's consolidated balance sheets included fixed payments to be made under executed settlement agreements and accrued estimated losses presented in the tables below:

 Total

 Current portion of Wildfire-related claims liabilities1

 $
 $
 $

 Long term wildfire-related claims liabilities2

 Total Balance at December 31, 2024
 $
 $
 $
 1,001

 Total

 Current portion of Wildfire-related claims liabilities1

 $
 $
 —
 $

 Long term wildfire-related claims liabilities2

 1,368

 Total Balance at December 31, 2023
 $
 $
 $
 1,398

 1.At December 31, 2024, current liabilities related to 2017/2018 Wildfire/Mudslide Events consisted of $ 29 million of settlements executed and $ 19 million of short-term payables under the SED Agreement. At December 31, 2023, current liabilities related to 2017/2018 Wildfire/Mudslide Events consisted of $ 16 million of settlements executed and $ 14 million of short-term payables under the SED Agreement.
 2.At December 31, 2024, long-term wildfire-related claims related to 2017/2018 Wildfire/Mudslide Events consisted of $ 38 million of long-term payables under the SED Agreement and $ 340 million of estimate of expected losses for remaining alleged and potential claims. At December 31, 2023, long-term wildfire-related claims related to 2017/2018 Wildfire/Mudslide Events consisted of $ 48 million of long-term payables under the SED Agreement and $ 637 million of estimate of expected losses for remaining alleged and potential claims.
 Edison International and SCE have accrued their best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events and at the low end of the estimated range of reasonably possible losses for each of the Other Wildfire Events as no amount within the range of reasonably possible losses for each such fire appears, at this time, to be a better estimate than any other amount within the range. While Edison International and SCE may incur a material loss in excess of the amounts accrued, they cannot estimate the upper end of the range of reasonably possible losses that may be incurred in connection with the 2017/2018 Wildfire/Mudslide Events or the Other Wildfire Events.
 The estimated losses for the 2017/2018 Wildfire/Mudslide Events do not include estimates of potential losses related to certain potential public entity plaintiff claims, including CAL OES's claim in the TKM litigation, for which the statute of limitations has been tolled, and for an individual plaintiff demand received in the first quarter of 2024 that continues to be analyzed and has not been substantiated, as losses from these alleged and potential claims are not estimable at this time.
 Management reviews its loss estimates for remaining alleged and potential claims related to wildfire litigation quarterly. The first quarter 2024 analysis with respect to the 2017/2018 Wildfire/Mudslide Events included a review of information received during the first quarter of 2024 about outstanding claims, including demands from most of the individual plaintiffs who had opted into the Woolsey Fire mediation program, and from settling claims through that quarter. As a result of management's reviews, SCE recorded an increase in estimated losses of $ 490 million for the 2017/2018 Wildfire/Mudslide Events during the first quarter of 2024.
 For the years ended December 31, 2024, 2023 and 2022, SCE's consolidated statements of income included charges for the estimated losses, net of expected recoveries, as follows:

 Year ended December 31, 2024

 Total

 Charge for wildfire-related claims
 $
 $
 $

 Expected insurance recoveries1

 —
 ( 96)
 ( 96)

 Expected recoveries through electric rates
 ( 27)
 ( 9)
 ( 36)

 Total pre-tax charge

 Income tax benefit
 ( 130)
 ( 42)
 ( 172)

 Total after-tax charge
 $
 $
 $

 Year ended December 31, 2023

 Total

 Charge for wildfire-related claims
 $
 $
 $

 Expected insurance recoveries1

 —
 ( 149)
 ( 149)

 Expected recoveries through electric rates
 ( 37)
 ( 2)
 ( 39)

 Total pre-tax charge

 Income tax benefit
 ( 165)
 ( 9)

 Total after-tax charge
 $
 $
 $

 Year ended December 31, 2022

 Total

 Charge for wildfire-related claims
 $
 1,296
 $
 $
 1,868

 Expected insurance recoveries1

 —
 ( 399)
 ( 399)

 Expected recoveries through electric rates
 ( 76)
 ( 162)
 ( 238)

 Total pre-tax charge
 1,220
 1,231

 Income tax benefit
 ( 341)
 ( 3)
 ( 344)

 Total after-tax charge
 $
 $
 $

 1.In 2024, 2023 and 2022, Edison Insurance Services, Inc. ("EIS"), a wholly-owned subsidiary of Edison International, incurred $ 4 million, $ 3 million and $ 9 million insurance expenses, respectively. These amounts were included in the insurance recoveries of SCE but were excluded from those of Edison International.
 In total, through December 31, 2024, SCE has recorded estimated losses of $ 11 billion, expected recoveries from insurance and third parties of $ 2.7 billion and expected recoveries through electric rates of $ 617 million related to the 2017/2018 Wildfire/Mudslide Events and the Other Wildfire Events. The after-tax net charges to earnings recorded through December 31, 2024, have been $ 5.6 billion.
 Recoveries
 SCE has exhausted expected insurance recoveries related to the 2017/2018 Wildfire/Mudslide Events. Expected recoveries from insurance recorded for the Other Wildfire Events are supported by SCE's insurance coverage for multiple policy years. Edison International and SCE record a receivable for insurance recoveries when recovery of a recorded loss is determined to be probable.
 Recovery of SCE's losses realized in connection with the Woolsey Fire and the Other Wildfire Events in excess of available insurance is subject to approval by regulators. The CPUC and FERC may not allow SCE to recover uninsured losses through electric rates, including by requiring refund of amounts recovered, if it is determined that such losses were not prudently incurred. Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates. SCE utilizes objectively determinable evidence to form its view on the probability of future recovery.
 While Edison International and SCE may incur material losses in excess of the amounts accrued for certain of the Other Wildfire Events, Edison International and SCE expect that additional losses incurred in connection with any such fire, other than for the Creek Fire, will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such additional losses after expected recoveries from insurance and through electric rates will not be material.
 As of December 31, 2024, SCE has recorded total expected recoveries of $ 2.7 billion from insurance, of $ 152 million within the WEMA and RMBA and $ 465 million within the FERC related balancing account related to the 2017/2018 Wildfire/Mudslide Events and the Other Wildfire Events.

 The following table sets forth total expected recoveries SCE has recorded since inception through December 31, 2024:

 Total

 Insurance recoveries
 $
 2,000
 $
 $
 2,718

 FERC recoveries

 CPUC- RMBA recoveries
 —

 CPUC-WEMA deferral
 —

 Total
 $
 2,440
 $
 $
 3,335

 The following tables summarize expected recoveries from insurance and through electric rates as of December 31, 2024 and 2023:

 Total

 Long-term insurance receivables
 $
 —
 $
 $

 FERC related balancing accounts

 CPUC-WEMA
 —

 Total
 $
 $
 $

 Total

 Long-term insurance receivables
 $
 —
 $
 $

 FERC related balancing accounts

 CPUC-WEMA
 —

 Total
 $
 $
 $

 For events that occurred in 2017 and early 2018, principally the Thomas and Koenigstein Fires and Montecito Mudslides, SCE had $ 1.0 billion of wildfire-specific insurance coverage, subject to a self-insured retention of $ 10 million per occurrence. For the Woolsey Fire, SCE had an additional $ 1.0 billion of wildfire-specific insurance coverage, subject to a self-insured retention of $ 10 million per occurrence. SCE has recovered $ 2.0 billion from its insurance carriers in relation to the claims related to the 2017/2018 Wildfire/Mudslide Events. SCE has recorded recoveries from insurance of $ 18 million related to the Creek Fire. No additional insurance is available for the Creek Fire because wildfire insurance for the period in which the fire was ignited has been almost fully exhausted as a result of the TKM litigation.
 SCE has approximately $ 1.2 billion of wildfire-specific insurance coverage for events that occurred during the period June 1, 2019 through June 30, 2020, subject to up to $ 165 million of co-insurance and self-insured retention, which resulted in net coverage of approximately $ 1.0 billion.
 SCE has approximately $ 1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2020 through June 30, 2021, subject to up to $ 130 million of self-insured retention and co-insurance per fire, which results in net coverage of approximately $ 870 million.
 SCE has approximately $ 1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2021 through June 30, 2022, subject to up to $ 163 million of self-insured retention and co-insurance per fire, which resulted in net coverage of approximately $ 837 million.
 SCE has approximately $ 1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2022 through June 30, 2023, subject to up to $ 63 million of self-insured retention and co-insurance per fire, which results in net coverage of approximately $ 937 million.
 SCE's wildfire insurance expense for the July 1, 2022 through June 30, 2023 policy period was approximately $ 450 million, of which $ 357 million was paid to commercial insurance carriers (commercial insurance carriers other than EIS are referred to herein as "Third-Party Commercial Insurers"). The difference between the Third-Party Commercial Insurer cost and total cost for the July 1, 2022 through June 30, 2023 policy period was paid in premiums to EIS (See Note

 18 for further information). Wildfire insurance premiums paid for the July 1, 2022 through June 30, 2023 policy period are being recovered through customer rates. In February 2025, an amendment was made to one of the EIS wildfire liability insurance policies. This amendment does not change the the amount of premiums paid to EIS and does not change the policy's total available insurance limit, but modifies how the limit is applied under the policy. As a result of this amendment, $ 50 million of the self-insured retention for a wildfire occurring during the July 1, 2022 through June 30, 2023 policy period, recorded in WEMA as of December 31, 2024, is now eligible for insurance reimbursement. Consequently, in 2025, EIS will record a $ 50 million wildfire insurance expense (by utilizing the premiums already collected as discussed above), and SCE will record the corresponding insurance recovery from EIS by applying a required credit to the WEMA.
 In May 2023, the CPUC allowed SCE to establish an expanded self-insurance program for wildfire-related costs that will be funded through CPUC-jurisdictional rates, in lieu of obtaining wildfire liability insurance from the commercial insurance market. Beginning on July 1, 2023, SCE implemented its customer-funded wildfire self-insurance program. In 2023 and 2024 SCE collected $ 150 million and $ 300 million, respectively, through CPUC-jurisdictional rates in support of SCE's customer-funded wildfire self-insurance program.
 In July 2024, the CPUC issued a decision in the 2025 GRC proceeding authorizing this self-insurance framework to continue through at least 2028, supporting a self-insurance fund of up to $ 1.0 billion per policy year. Through 2028, $ 300 million will be collected annually until a total available self-insurance accrual amount of $ 1.0 billion is achieved. If losses are accrued for wildfire-related claims for wildfires that occur between July 1, 2023 and the end of 2028, customer rates will be increased in subsequent years, as needed, to allow for full recovery of the amounts accrued up to $ 1.0 billion per policy year, subject to a shareholder contribution of 2.5 % of any self-insurance costs ultimately paid exceeding $ 500 million in any policy year, up to a maximum annual contribution of $ 12.5 million per policy year. SCE's self-insurance program meets its obligation to maintain reasonable insurance coverage under AB 1054 for the January 1, 2025 through December 31, 2025 period.
 Recoveries through Electric Rates

 CPUC recoveries pre-AB 1054

 Regulatory recovery of SCE's losses realized in connection with the 2017/2018 Wildfire/Mudslide Events in excess of available insurance is subject to approval by regulators. Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates. SCE utilizes objectively determinable evidence to form its view on probability of future recovery. The only directly comparable precedent in which a California investor-owned utility sought recovery for uninsured wildfire claims related costs and the CPUC made a prudency determination is SDG&E's requests for cost recovery related to 2007 wildfire activity, where the FERC allowed recovery of all FERC-jurisdictional wildfire claims related costs while the CPUC rejected recovery of all CPUC-jurisdictional wildfire claims related costs based on a determination that SDG&E did not meet the CPUC's prudency standard ("SDG&E Decision"). The SDG&E Decision is evidence of a California investor-owned utility seeking recovery for uninsured wildfire-related costs and FERC allowing recovery of all FERC-jurisdictional wildfire-related costs while the CPUC rejected recovery of all CPUC-jurisdictional wildfire-related costs based on a determination that the utility did not meet the CPUC's prudency standard.
 In August 2023, SCE filed an application to seek CPUC-jurisdictional rate recovery of prudently incurred losses related to the Thomas Fire, the Koenigstein Fire and the Montecito Mudslides, consisting of uninsured claims and associated costs, including legal costs and financing costs. In January 2025, the CPUC approved the TKM Settlement Agreement and closed the proceeding. Parties to the proceeding may file an application for rehearing through March 10, 2025. Under the TKM Settlement Agreement, SCE is authorized to recover 60 %, or approximately $ 1.6 billion, of approximately $ 2.7 billion of losses, consisting of approximately $ 1.3 billion of uninsured claims paid as of May 31, 2024 and $ 0.3 billion of associated costs, composed of legal fees and financing costs incurred as of May 31, 2024 and estimated ongoing financing costs. SCE is also authorized to recover 60 % of claims paid and related costs incurred after May 31, 2024, other than for $ 125 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. SCE will record a regulatory asset for recoveries permitted under the TKM Settlement Agreement in the first quarter of 2025. Under the TKM Settlement Agreement, SCE is also authorized to recover approximately $ 55 million of approximately $ 65 million in incremental restoration costs, inclusive of operations and maintenance expenses, incurred related to the Thomas and Koenigstein Fires.
 In October 2024, SCE filed an application (the "Woolsey Application") to seek CPUC-jurisdictional rate recovery of $ 5.4 billion of prudently incurred losses related to the Woolsey Fire, consisting of approximately $ 4.4 billion of uninsured claims paid as of August 31, 2024 and $ 1.0 billion of associated costs, composed of legal and financing costs incurred as of August 31, 2024 and estimated ongoing financing costs. The CPUC may not allow SCE to recover uninsured losses related to the Woolsey Fire and through electric rates if it is determined that such losses were not prudently incurred. SCE is also

 seeking recovery of approximately $ 84 million in restoration costs in the proceeding. These assets are impaired if the restoration costs are permanently disallowed by the CPUC.
 The CPUC did not make a determination regarding SCE's prudency when it approved the TKM Settlement Agreement. Therefore, notwithstanding CPUC approval of the TKM Settlement Agreement, SCE believes that the CPUC's interpretation and application of the prudency standard to SDG&E continues to create substantial uncertainty regarding how that standard will be applied to an investor-owned utility in wildfire cost-recovery proceedings for fires ignited prior to July 12, 2019. Consequently, SCE is unable to estimate the uninsured CPUC-jurisdictional claims related costs related to the Woolsey Fire or Creek Fire, both pre-AB 1054 events, that are probable of future recovery, and will not record a regulatory asset for recoveries related to the Woolsey Fire or Creek Fire in connection with the approval of the TKM Settlement Agreement. SCE will continue to evaluate the facts and circumstances of cost recovery proceedings applicable to pre-AB 1054 wildfires to determine if and when a regulatory asset for pre-AB 1054 wildfire events may be recorded.
 CPUC recoveries post-AB 1054
 The SDG&E Decision was prior to the adoption of AB 1054 on July 12, 2019, after which date AB 1054 clarified that the CPUC must find a utility to be prudent if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken in good faith under similar circumstances, at the relevant point in time, and based on the information available at that time. Further, utilities with a valid safety certification at the time of the relevant wildfire will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates serious doubt as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to prove its conduct was prudent.
 Each of the Other Wildfire Events discussed above, with the exception of the Creek Fire, was ignited after July 12, 2019, and SCE has held a valid safety certification since July 15, 2019. While a California investor-owned utility has not yet sought a prudency review related to recovery for uninsured claims and other costs related to wildfires ignited after the adoption of AB 1054, SCE believes that for fires ignited after July 12, 2019, and for investor-owned utilities holding a safety certification at the time of the fire, the CPUC will apply a standard of review similar to that applied by the FERC which presumes all costs requested by an investor-owned utility are reasonable and prudent unless serious doubt as to the reasonableness of the utility's conduct is created. As such, SCE has concluded, at this time, that uninsured CPUC-jurisdictional wildfire-related costs related to those Other Wildfire Events occurring after AB 1054 that it has deferred as regulatory assets are probable of recovery through electric rates. SCE will continue to evaluate the probability of recovery based on available evidence, including regulatory decisions, including any CPUC decisions illustrating the interpretation and/or application of the prudency standard under AB 1054, and, for each applicable fire, evidence that could create serious doubt as to the reasonableness of SCE's conduct relative to that fire. The CPUC may not allow SCE to recover uninsured losses related to the Other Wildfire Events through electric rates if it is determined that such losses were not prudently incurred.
 FERC recoveries
 Through the operation of its FERC Formula Rate, and based upon the precedent established in SDG&E's recovery of FERC-jurisdictional wildfire-related costs, SCE believes it is probable it will recover its FERC-jurisdictional costs related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events. FERC recoveries are subject to refund, and SCE will continue to evaluate the probability of recovery of FERC-jurisdictional costs related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events based on available evidence, including any FERC decisions to allow or disallow recovery of FERC-jurisdictional wildfire related costs based on a state regulator's decision on whether to permit recovery of related costs. FERC recoveries related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events are subject to refund.
 Subsequent events Eaton Fire
 In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage and service outages for SCE customers. One of the largest of these wildfires, the Eaton Fire, ignited in SCE's service area in Los Angeles County and spread under conditions of an extreme Santa Ana windstorm.
 According to preliminary information provided by CAL FIRE, the Eaton Fire burned approximately 14,000 acres; destroyed approximately 6,018 single residence structures, 3,146 other minor structures, 96 multiple residences and 158 mixed commercial/residential and nonresidential commercial structures; damaged approximately 750 residential structures, 260 other minor structures, 28 multiple residences and 35 mixed commercial/residential and nonresidential commercial structures and resulted in 17 confirmed civilian fatalities and 9 confirmed fire personnel injuries/illnesses. In addition, fire authorities have estimated suppression costs at approximately $ 100 million.
 The Los Angeles County Fire Department is leading the investigation into the origin and cause of the Eaton Fire, with the assistance of CAL FIRE, and has identified a preliminary area of origin of the fire. SCE has transmission facilities in the

 preliminary area of origin. As part of its investigation, the Los Angeles County Fire Department has requested that SCE preserve in-place its equipment in the preliminary area of origin. The SED is also conducting an investigation with respect to the Eaton Fire.
 Multiple lawsuits related to the Eaton Fire have been initiated against SCE and Edison International. SCE's ongoing internal review into the facts and circumstances of the Eaton Fire is complex and will require significant time. SCE's review includes ongoing inspections of its facilities and records and of third-party information, including analysis of concerning images and videos that suggest a possible link to SCE's transmission facilities in the preliminary area of origin. As of February 27, 2025, based on the information it has reviewed, SCE has not determined whether its equipment was associated with the ignition of the Eaton Fire.
 As required by applicable accounting standards, SCE is continuing to assess the likelihood of potential losses related to the Eaton Fire and cannot estimate the range of reasonably possible losses that could be incurred in connection with the Eaton Fire.
 Environmental Remediation
 SCE records its environmental remediation liabilities when site assessments and/or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. SCE reviews its sites and measures the liability quarterly, by assessing a range of reasonably likely costs for each identified site using currently available information, including existing technology, presently enacted laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties. These estimates include costs for site investigations, remediation, operation and maintenance, monitoring and site closure. Unless there is a single probable amount, SCE records the low end of this reasonably likely range of costs (reflected in " Other long-term liabilities ") at undiscounted amounts as timing of cash flows is uncertain.
 At December 31, 2024, SCE's recorded estimated minimum liability to remediate its 21 identified material sites (sites with a liability balance as of December 31, 2024, in which the upper end of the range of the costs is at least $ 1 million) was $ 232 million, including $ 154 million related to San Onofre. In addition to these sites, SCE also has 19 immaterial sites with a liability balance on December 31, 2024 for which the total minimum recorded liability was $ 3 million. Of the $ 235 million total environmental remediation liability for SCE, $ 222 million has been recorded as a regulatory asset. SCE expects to recover $ 35 million through an incentive mechanism that allows SCE to recover 90 % of its environmental remediation costs at certain sites (SCE may request to include additional sites in this mechanism), and $ 187 million through proceedings that allow SCE to recover up to 100 % of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.
 The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $ 118 million and $ 2 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.
 SCE expects to clean up and mitigate its identified sites over a period of up to approximately 35 years, though some sites may require a longer time period. Remediation costs for each of the next 5 years are expected to range from $ 9 million to $ 21 million. Costs incurred for years ended December 31, 2024, 2023 and 2022 were $ 17 million, $ 11 million and $ 7 million, respectively, and were included in the "Operation and maintenance" expense on the consolidated statements of income.
 Based upon the CPUC's regulatory treatment of environmental remediation costs incurred at SCE, SCE believes that costs ultimately recorded will not materially affect its results of operations, financial position or cash flows. There can be no assurance, however, that future developments, including additional information about existing sites or the identification of new sites, will not require material revisions to estimates.
 Nuclear Insurance
 Federal law limits public offsite liability claims for bodily injury and property damage from a nuclear incident to the amount of available financial protection, which is currently approximately $ 560 million for San Onofre and $ 16.3 billion for Palo Verde. As of January 1, 2024, SCE and other owners of San Onofre and Palo Verde have purchased the maximum

 private primary insurance available ($ 500 million) through a Facility Form issued by American Nuclear Insurers ("ANI"). In the case of San Onofre, the balance is covered by a US Government indemnity. In the case of Palo Verde, the balance is covered by a loss sharing program among nuclear reactor licensees. If a nuclear incident at any licensed reactor in the United States, which is participating in the loss sharing program, results in claims and/or costs which exceed the primary insurance at that plant site, all participating nuclear reactor licensees could be required to contribute their share of the liability in the form of a deferred premium.
 The ANI Facility Form coverage includes broad liability protection for bodily injury or offsite property damage caused by the nuclear energy hazard at San Onofre or Palo Verde, or while radioactive material is in transit to or from San Onofre or Palo Verde. The Facility Form, however, includes several exclusions. First, it excludes onsite property damage to the nuclear facility itself and onsite cleanup costs, but as discussed below SCE maintains separate Nuclear Electric Insurance Limited ("NEIL") property damage coverage for such events. Second, tort claims of onsite workers are excluded, but SCE also maintains an ANI Master Worker Form policy that can provide coverage for non-licensee workers. This program provides a shared industry aggregate limit of $ 500 million. Industry losses covered by this program could reduce limits available to SCE. Third, offsite environmental costs arising out of government orders or directives, including those issued under the Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA, are excluded, with exceptions from clearly identifiable accidents.
 SCE withdrew from participation in the secondary insurance pool for San Onofre for offsite liability insurance effective January 5, 2018. Based on its ownership interests in Palo Verde, SCE could be required to pay a maximum of approximately $ 79 million per nuclear incident for future incidents. However, it would have to pay no more than approximately $ 12 million per future incident in any one year. Based on its ownership interests in San Onofre and Palo Verde prior to January 5, 2018, SCE could be required to pay a maximum of approximately $ 255 million per nuclear incident and a maximum of $ 38 million per year per incident for liabilities arising from events prior to January 5, 2018, although SCE is not aware of any such events. If the public liability limit above is insufficient, federal law contemplates that additional funds may be appropriated by Congress. This could include an additional assessment on all licensed reactor operators as a measure for raising further federal revenue.
 SCE is a member of NEIL, a mutual insurance company owned by entities with nuclear facilities. NEIL provides insurance for nuclear property damage, including damages caused by acts of terrorism up to specified limits, and for accidental outages for active facilities. The amount of nuclear property damage insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $ 50 million and $ 1.1 billion, respectively. These policies include coverage for decontamination liability. Additional outage insurance covers part of replacement power expenses during an accident-related nuclear unit outage. The accidental outage insurance at San Onofre has been canceled as a result of the permanent retirement, but that insurance continues to be in effect at Palo Verde.
 If NEIL losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $ 17 million per year. Insurance premiums are charged to operating expense.

 Note 13. Leases
 Leases as Lessee
 SCE enters into various agreements to purchase power, electric capacity and other energy products that may be accounted for as leases when SCE has dispatch rights that determine when and how a plant runs. SCE also leases property and equipment primarily related to vehicles, office space and other equipment. The terms of the lease contracts included in the table below are primarily 15 to 20 years for PPA leases, 3 to 72 years for office leases, and 5 to 13 years for the remaining other operating leases. Finance leases are immaterial to the periods presented.
 The following table summarizes SCE's future lease payments for operating leases as of December 31, 2024:

 PPA Operating Leases
 Other Operating Leases1

 2025
 $
 $

 2026

 2027

 2028

 2029

 Thereafter

 Total lease payments
 1,146

 Amount representing interest

 Lease liabilities
 $
 $

 1Excludes escalation clauses based on consumer price or other indices and residual value guarantees that are not considered probable at the commencement date of the lease.
 The timing of SCE's recognition of the lease expense conforms to ratemaking treatment for SCE's recovery of the cost of electricity and is included in purchased power for PPA operating leases. The following table summarizes the components of SCE's lease expense:

 2024
 2023
 2022

 PPA leases:

 Operating lease cost
 $
 $
 $

 Variable lease cost1

 1,700
 2,277
 2,661

 Total PPA lease cost
 1,815
 2,780
 3,241

 Other operating leases cost

 Total lease cost
 $
 1,879
 $
 2,836
 $
 3,293

 1Includes lease costs from legacy renewable energy contracts where payments are based on contingent external factors such as wind, hydro and solar power generation.

 Other information related to leases was as follows:

 (in millions, except lease term and discount rate)
 2024
 2023
 2022

 Cash paid for amounts included in the measurement of lease liabilities:

 Operating cash flows from:

 PPA operating leases
 $
 $
 $

 Other operating leases

 ROU assets obtained in exchange for lease obligations:

 PPA operating leases
 $
 $
 $

 Other operating leases

 Weighted average remaining lease term (in years):

 PPA operating leases
 12.50
 13.37
 9.42

 Other operating leases
 8.86
 9.56
 10.38

 Weighted average discount rate:

 PPA operating leases
 4.30 %
 4.30 %
 2.95 %

 Other operating leases
 4.50 %
 4.22 %
 3.78 %

 Leases as Lessor
 SCE also enters into operating leases to rent certain land and facilities as a lessor. These leases primarily have terms that range from 15 to 65 years. During the years ended December 31, 2024, 2023 and 2022, SCE recognized lease income of $ 18 million, $ 17 million and $ 18 million, respectively, which is included in operating revenue on the consolidated statements of income. At December 31, 2024, the undiscounted cash flow expected to be received from lease payments for the remaining years is as follows:

 2025
 $

 2026

 2027

 2028

 2029

 Thereafter

 Total
 $

 Note 14. Equity
 Common Stock
 Stock Repurchase Programs
 On December 12, 2024, the Edison International Board of Directors authorized a stock repurchase program effective February 20, 2025 for repurchase of up to $ 75 million of its common stock until February 18, 2026 ("2025 Repurchase Program"). The Repurchase Program will be used to offset dilution from common stock issued under Edison International's long-term incentive compensation programs and will be funded using Edison International's working capital.
 The timing and the amount of any repurchased common stock will be determined by Edison International's management based on their evaluation of market conditions and other factors. The 2025 Repurchase Program may be executed through various methods, including open market purchases, privately negotiated transactions, and other transactions in accordance with applicable securities laws. Any repurchased shares of common stock will be retired. The 2025 Repurchase Program does not obligate Edison International to acquire any particular amount of common stock, and it may be suspended or discontinued at any time at its discretion.

 On July 25, 2024, Edison International announced a stock repurchase program effective July 29, 2024 for repurchase of up to $ 200 million of its common stock until December 31, 2025 ("2024 Repurchase Program"). The 2024 Repurchase Program was used to offset dilution from common stock issued under Edison International's long-term incentive compensation programs and was funded using Edison International's working capital.
 During the year ended December 31, 2024, Edison International repurchased and retired 2,412,203 shares under the 2024 Repurchase Program for an average price of $ 82.91 per share. As of December 31, 2024, no authorized repurchase amount remained under the 2024 Share Repurchase Program.
 At-the-market Program
 As of December 31, 2024, Edison International had not issued any shares through its "at-the-market" ("ATM") program established in August 2022. Under the ATM program, Edison International may sell shares of its common stock having an aggregate sales price of up to $ 500 million. Edison International has no obligation to sell the remaining shares available under the ATM program. On February 21, 2025, Edison International delivered notice to the agents to terminate the ATM program, which was effective February 24, 2025.
 Preferred Stock
 As of December 31, 2024, Edison International had 1,159,317 shares of 5.375 % Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series A ("Series A Preferred Stock") and 503,454 shares of 5.00 % Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series B ("Series B Preferred Stock") outstanding, each with a liquidation value of $ 1,000 per share. The dividends are payable on a semi-annual basis and will be reset every five years beginning on March 15, 2026 and March 15, 2027, for Series A Preferred Stock and Series B Preferred Stock, respectively, to equal the then-current five-year U.S. Treasury rate plus a spread.
 In the first and second quarter of 2024, Edison International repurchased 20,000 shares and 9,000 shares, respectively, of its Series B Preferred Stock via open market repurchases for $ 19 million (at an average price of $ 952) and $ 9 million (at an average price of $ 967), respectively, including accrued and unpaid dividends. In December 2023, Edison International repurchased 29,186 shares of its Series A Preferred Stock and 133,323 shares of its Series B Preferred Stock via open market repurchases for $ 28 million (at an average price of $ 971) and $ 127 million (at an average price of $ 955), respectively, including accrued and unpaid dividends. In November 2023, Edison International, through a tender offer, repurchased 61,497 shares of its Series A Preferred Stock and 84,223 shares of its Series B Preferred Stock for $ 57 million (at an average price of $ 925) and $ 76 million (at an average price of $ 904), respectively, including accrued and unpaid dividends. Edison International recognized a total net gain of $ 1 million and $ 16 million for the years ended December 31, 2024 and 2023, respectively, from the repurchases as reflected in "Preferred stock dividend requirements of Edison International" on the consolidated statements of income.
 Edison International may, at its option, redeem its preferred stocks in whole or in part during certain periods of time prior to each of the dividend reset dates at a price equal to $ 1,000 per share plus any accumulated and unpaid dividends. Edison International may also, at its option, redeem the preferred stocks in whole but not in part at a price equal to $ 1,020 per share plus any accumulated and unpaid dividends within a certain period of time following any change in the criteria rating agencies use that would have adverse effects on the equity credit attributed by rating agencies to the preferred stocks.
 The preferred stocks rank senior to Edison International's common stock with respect to dividends rights and distribution rights upon liquidation. The preferred stocks are not subject to any mandatory sinking fund, retirement fund, purchase fund or other similar provisions. Holders of the shares of the preferred stocks do not have the right to require Edison International to repurchase or redeem shares of the preferred stocks.
 Preferred and Preference Stock of Utility
 SCE's authorized shares are: $ 100 cumulative preferred – 12 million shares, $ 25 cumulative preferred – 24 million shares and preference with no par value – 50 million shares. There were no preferred shares issued or outstanding as of December 31, 2024 and 2023.
 Shares of SCE's preference stock rank senior to SCE's common stock with respect to dividend rights and distribution rights upon liquidation. SCE's outstanding preference shares are not subject to mandatory redemption and there is no sinking fund requirement for redemptions or repurchases of preference shares. There are no dividends in arrears for the preference shares.

 The following table summarizes preference stocks (dividends declared per share are for 2024):

 Issue Date
Outstanding
 Redemption
Price per
Share
 Dividends
Declared per
Share

 (in millions, except shares and per share amounts)
 2024
 2023

 No par value (cumulative):

 3-month SOFR+ 4.199 % Series E

 2012
 —
 $
 1,000
 $
 24.418
 $
 —
 $

 5.10 % Series G

 2013
 88,004
 2,500
 127.500

 3-month SOFR+ 2.99 % Series H

 2014
 —
 2,500
 187.776
 —

 5.375 % Series J

 2015
 130,004
 2,500
 134.375

 5.45 % Series K

 2016
 120,004
 2,500
 136.250

 5.00 % Series L

 2017
 190,004
 2,500
 125.000

 7.50 % Series M

 2023
 220,004
 2,500
 199.479

 6.95 % Series N

 2024
 140,004
 2,500
 102.319
 —

 SCE's preference stock
 2,220
 2,495

 Less: issuance costs
 ( 45)
 ( 52)

 Edison International's preference stock of utility
 $
 2,175
 $
 2,443

 Shares of Series E, G, H and L preference stock may be redeemed at par, in whole or in part. Shares of Series J, K, and M preference stock may be redeemed at par, in whole, but not in part, at any time prior to September 15, 2025, March 15, 2026, and November 22, 2028, respectively, if certain changes in tax or investment company law or interpretation (or applicable rating agency equity credit criteria for Series L and M only) occur and certain other conditions are satisfied. On or after September 15, 2025, March 15, 2026, and November 22, 2028, SCE may redeem the Series J, K, and M shares, respectively, at par, in whole or in part. For shares of Series J and K preference stock, distributions will accrue and be payable at a floating rate from and including September 15, 2025 and March 15, 2026, respectively. In May 2024, $ 350 million Series N preference stock was issued. The proceeds were used to redeem all of the Series E preference stock. In November 2024, Series H preference stock was redeemed.
 Shares of Series G, H, J, K, L, M and N preference stock were issued to SCE Trust II, SCE Trust III, SCE Trust IV, SCE Trust V, SCE Trust VI, SCE Trust VII and SCE Trust VIII, respectively, special purpose entities formed to issue trust securities to the public. The trust securities do not have a maturity date and upon redemption of any shares of the series of preference stock, a corresponding dollar amount of the trust securities will be redeemed by the applicable trust. The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities, if and when the SCE's Board of Directors declares and makes dividend payments on the related preference stock.

 Note 15. Accumulated Other Comprehensive Loss
 The changes in accumulated other comprehensive loss, net of tax, consist of:

 SCE

 2024
 2023
 2024
 2023

 Beginning balance
 $
 ( 9)
 $
 ( 11)
 $
 ( 12)
 $
 ( 8)

 Pension and PBOP:

 Other comprehensive (loss) income before reclassifications
 ( 2)
 ( 5)

 Reclassified from accumulated other comprehensive loss1

 Foreign currency translation adjustments
 —
 —
 —

 Change
 ( 4)

 Ending balance
 $
 —
 $
 ( 9)
 $
 ( 9)
 $
 ( 12)

 1These items are included in the computation of net periodic pension and PBOP Plan expense. See Note 9 for additional information.

 Note 16. Other Income, Net
 Other income net of expenses is as follows:

 2024
 2023
 2022

 SCE other income (expense):

 Equity AFUDC
 $
 $
 $

 Increase in cash surrender value of life insurance policies and life insurance benefits

 Interest income

 Net periodic benefit income – non-service components

 Civic, political and related activities and donations
 ( 63)
 ( 42)
 ( 42)

 Other
 ( 14)
 ( 16)
 ( 16)

 Total SCE other income, net

 Other income (expense) of Edison International Parent and Other:

 Net (losses) gains on equity securities
 —
 ( 3)

 Interest income and other

 Total Edison International other income, net
 $
 $
 $

 Note 17. Supplemental Cash Flows Information
 Supplemental cash flows information is:

 SCE

 2024
 2023
 2022
 2024
 2023
 2022

 Cash payments (receipts):

 Interest, net of amounts capitalized
 $
 1,588
 $
 1,401
 $
 1,001
 $
 1,306
 $
 1,155
 $

 Income taxes, net
 —
 ( 49)
 —
 ( 49)

 Non-cash financing and investing activities:

 Dividends declared but not paid:

 Common stock

 Preference stock of SCE
 —
 —

 Details of debt exchange:

 Pollution-control bonds redeemed ( 2.625 %)

 —
 ( 135)
 —
 —
 ( 135)
 —

 Pollution-control bonds remarketed ( 4.50 %)

 —
 —
 —
 —

 SCE's accrued capital expenditures for the years ended December 31, 2024, 2023, and 2022 were $ 644 million, $ 680 million, and $ 652 million, respectively. Accrued capital expenditures are included in investing activities in the consolidated statements of cash flows in the period paid.

 Note 18. Related-Party Transactions
 Edison International and SCE provide and receive various services to and from its subsidiaries and affiliates. Services provided to Edison International by SCE are priced at fully loaded cost (i.e., direct cost of goods or service and allocation of overhead cost). Specified administrative services performed by Edison International or SCE employees, such as payroll and employee benefit programs, are shared among all affiliates of Edison International. Costs are allocated based on one of the following formulas: percentage of time worked, equity in investment and advances, number of employees, or multi-factor (operating revenue, operating expenses, total assets and number of employees). Edison International allocates various corporate administrative and general costs to SCE and other subsidiaries using established allocation factors.
 For the years ended December 31, 2024 and 2023, SCE did not purchase wildfire liability insurance from EIS. Beginning on July 1, 2023, in lieu of obtaining wildfire liability insurance from the commercial insurance market, SCE implemented its customer-funded wildfire self-insurance program. For the year ended December 31, 2022, SCE purchased wildfire liability insurance for premiums of $ 273 million from EIS. EIS fully reinsured the exposure for these policies through the commercial reinsurance market, with reinsurance limits and premiums equal to those of the insurance purchased by SCE, except for a contract for a premium of $ 93 million for the 12 months ended June 30, 2023 under which EIS provided insurance protection to SCE. SCE recorded the premium as insurance expense and recorded an equal amount of revenue due to customer funding through regulatory cost recovery mechanisms, therefore there was no earnings impact on SCE's consolidated statements of income. EIS recorded the premium as insurance revenue. On the Edison International consolidated statements of income, the EIS insurance revenue was eliminated with SCE's insurance expense, therefore the SCE customer revenues increased the earnings of Edison International. The amount of insurance expense and corresponding revenue was $ 44 million for the year ended December 31, 2023. The expected insurance recoveries from previously purchased wildfire-related insurance from EIS included in SCE's consolidated balance sheets were $ 303 million and $ 355 million at December 31, 2024 and December 31, 2023, respectively. The expense for wildfire-related insurance premiums paid to EIS was $ 132 million and $ 213 million for the years ended December 31, 2023 and 2022, respectively.
 Edison International Foundation ("EIXF") is an unconsolidated not-for-profit organization. Edison International does not have title to, and cannot receive contributions back from, EIXF. Edison International made contributions to EIXF of $ 19 million for the year ended December 31, 2024, which was reflected in "Other income, net" on Edison International's consolidated statements of income. There were no contributions in 2023 and 2022.

 CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
 None.

 CONTROLS AND PROCEDURES
 Disclosure Controls and Procedures
 Based on an evaluation of Edison International's and SCE's disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), as of December 31, 2024, Edison International's and SCE's respective principal executive officers and principal financial officers have concluded that such controls and procedures are effective to ensure that information required to be disclosed by Edison International and SCE in reports that the companies file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC rules and forms. In addition, Edison International's and SCE's respective principal executive officers and principal financial officers have concluded that such controls and procedures were effective in ensuring that information required to be disclosed by Edison International and SCE in the reports that Edison International and SCE file or submit under the Exchange Act is accumulated and communicated to Edison International's and SCE's management, including Edison International's and SCE's respective principal executive officers and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
 Management's Report on Internal Control Over Financial Reporting
 Edison International's and SCE's respective management are responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f), for Edison International and its subsidiaries and SCE, respectively. Under the supervision and with the participation of their respective principal executive officer and principal financial officer, Edison International's and SCE's management conducted an evaluation of the effectiveness of their respective internal controls over financial reporting based on the framework set forth in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on their evaluations under the COSO framework, Edison International's and SCE's respective management concluded that Edison International's and SCE's respective internal controls over financial reporting were effective as of December 31, 2024. Edison International's internal control over financial reporting as of December 31, 2024 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report included in this filing, which is incorporated herein by this reference. This annual report does not include an attestation report of SCE's independent registered public accounting firm regarding internal control over financial reporting. Management's report for SCE is not subject to attestation by the independent registered public accounting firm.
 Changes in Internal Control Over Financial Reporting
 There were no changes in Edison International's or SCE's internal control over financial reporting during the fourth quarter of 2024 that have materially affected, or are reasonably likely to materially affect, Edison International's or SCE's internal control over financial reporting.
 Jointly Owned Utility Plant
 Edison International's and SCE's respective scope of evaluation of internal control over financial reporting includes their Jointly Owned Utility Projects.

 BUSINESS

 CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION
 Edison International was incorporated in 1987 as the parent holding company of SCE, a California public utility incorporated in 1909. Edison International also owns Trio, a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers.
 The principal executive office of Edison International is located at 2244 Walnut Grove Avenue, P.O. Box 976, Rosemead, California 91770, and Edison International's telephone numbers is (626) 302-2222. The principal executive office of SCE is located at 2244 Walnut Grove Avenue, P.O. Box 800, Rosemead, California 91770, and SCEs telephone numbers is (626) 302-1212.
 This is a combined Annual Report on Form 10-K for Edison International and SCE. Edison International and SCE make available at www.edisoninvestor.com: Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, Proxy Statements and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act, as soon as reasonably practicable after Edison International and SCE electronically file such material with, or furnishes it to, the SEC. Such reports are also available on the SEC's internet website at www.sec.gov. The information contained on, or connected to, the Edison investor website is not incorporated by reference into this report.

 Subsidiaries of Edison International
 SCE – Public Utility
 SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity through SCE's electrical infrastructure to an approximately 50,000 square-mile area of southern California. SCE serves approximately 5 million customers in its service area. As of December 31, 2024, SCE's total number of customers by class were as follows:

 (in thousands)
 2024
 2023
 2022

 Residential
 4,618
 4,576
 4,541

 Commercial

 Industrial

 Public authorities

 Agricultural and other

 Total
 5,321
 5,279
 5,244

 CPUC and FERC rates decouple authorized revenue from the volume of electricity sales and the price of energy procured so that SCE has the opportunity to receive revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold does not have a direct impact on SCE's financial results. See "SCE—Overview of Ratemaking Process—CPUC" and "—FERC" for further information.
 Trio – Energy Service Provider
 Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers. Trio aims to provide energy solutions that address cost, carbon and complex choices for its customers.

 Regulation of Edison International as a Holding Company
 As a public utility holding company, Edison International is subject to the Public Utility Holding Company Act. The Public Utility Holding Company Act primarily obligates Edison International and its utility subsidiaries to provide access to their books and records to the FERC and the CPUC for ratemaking purposes.
 Edison International is not a public utility and its capital structure is not regulated by the CPUC. The 1988 CPUC decision authorizing SCE to reorganize into a holding company structure, however, imposed certain obligations on Edison International and its affiliates. These obligations include a requirement that SCE's dividend policy continue to be established by the SCE Board of Directors as though SCE were a stand-alone utility company, and that the capital requirements of SCE, as deemed to be necessary to meet SCE's electricity service obligations, shall receive first priority from the Boards of Directors of Edison International and SCE. The CPUC has also promulgated Affiliate Transaction Rules, which, among other requirements, prohibit holding companies from (1) being used as a conduit to provide non-public information to a utility's affiliates and (2) causing or abetting a utility's violation of the rules, including providing preferential treatment to its affiliates.

 Human Capital
 At December 31, 2024, Edison International had an aggregate of 14,013 employees (excluding interns and employees on leaves of absence), of which 13,483 were full-time employees of SCE or its subsidiaries. In addition to employees, SCE's workforce includes a significant number of contract workers who support SCE's operations. Among these contract workers are Safety Tier 1 Contractors. SCE estimates, based on contractors' self-reported hours worked and a 2,080-hour work year, that there were approximately 8,798 full-time equivalent Safety Tier 1 Contractors supporting SCE operations during 2024. All Safety Tier 1 Contractors engaged in decommissioning activities at San Onofre are managed by the DGC. In addition to Safety Tier 1 Contractors, SCE also uses other contract workers to support its transmission and distribution, vegetation management, information technology and customer service activities.
 Approximately 4,300 of SCE's employees are represented by the International Brotherhood of Electrical Workers ("IBEW"). In February 2023, the IBEW membership ratified new collective bargaining agreements for the period January 1, 2023 through December 31, 2025. SCE continues to negotiate agreements with additional employee groups who subsequently certified IBEW as their bargaining representative. A substantial number of SCE's contract workers are also unionized.
 Edison International focuses on various human capital measures and objectives in managing its business, including measures and objectives related to safety, diversity, equity and inclusion and workforce continuity.
 Safety
 Safety is the first of Edison International's core values. Edison International is committed to fostering and maintaining a safe environment for its employees, contract workers, customers, and the public. Over the past several years, Edison International has intensified its efforts to improve workforce safety, including an increased focus on, and investment in, maturing a culture of safety ownership among its workforce that empowers employees and contract workers to own their safety, support their team members' safety and contribute to a safe work environment.
 Edison International takes efforts to eliminate fatalities and serious injuries, and reduce all injuries in our employee and contractor workforce. Edison International also continues to enhance its workforce safety culture. For instance, SCE uses safety culture assessments for both employee and contractors to measure progress toward improving safety culture. Additionally, all full-time employees are provided with regular safety-related training, particularly for those who work in proximity to high-voltage electrical equipment and other high-risk activities.
 SCE has implemented a people and systems safety plan for high hazard organizations. This plan is driven by SCE's Safety Management System ("SMS") and safety culture improvement efforts. Foundational to the SMS is the safety risk management pillar that identifies and prioritizes risks and mitigations based on several factors, including worker and leader input. The SMS strives to enable safety culture improvements for leader ownership and accountability. Examples of key risk mitigations targeted by the SMS include reducing the risk of electrical contact in underground structures and implementing new work methods to reduce fall risk.
 In 2024, SCE increased oversight of its contracted workforce through hiring of additional safety advisors and utilization of third-party observers. Similar to prior years, SCE implemented contractor initiatives to provide additional education on safe work practices, enhance risk awareness and better streamline understanding of SCE expectations. As part of SCE's safety protocols and contractor safety efforts, it forms incident review teams to address all contractor serious injury incidents, and related corrective actions. The respective contractors are then required to perform a cause evaluation to determine causes and learnings for each incident. Incident review outcomes including any work practice changes, rule updates, and new tools are shared and communicated to SCE employees and contractors for their knowledge, awareness, and implementation.

 Edison International also uses various measures to assess safety performance, including, without limitation, fatalities and serious injury rates for employees and contract workers. The following represents data for 2024:

 Employee work-related fatalities

 Employee EEI Serious Injuries

 Employee EEI SIF Rate1

 0.126

 Employee DART Rate2

 1.53

 Contractor work-related fatalities3

 Safety Tier 1 Contractor EEI Serious Injuries3

 Safety Tier 1 Contractor EEI SIF Rate1,3

 0.20

 Safety Tier 1 Contractor DART Rate2,3

 0.34

 1EEI SIF Rate is calculated by multiplying the total number of 2024 EEI SIF incidents (classified by SCE on or before January 16, 2025) by 200,000 and then dividing by the total number of reported hours worked.
 2DART Rate is calculated by multiplying the number of 2024 DARTs (reported to SCE on or before January 10, 2025 for Safety Tier 1 Contractors and classified as a DART by SCE on or before January 16, 2025 for employees) by 200,000 and then dividing by the total number of reported hours worked. The 2025 DART Rates may change based on information received by SCE after January 10, 2025, for Safety Tier 1 Contractors and after January 16, 2025 for employees.
 3Represents SCE contractor safety data and data provided by the DGC for contractors that undertake a significant scope of decommissioning activities at San Onofre.
 Diversity, Equity and Inclusion
 Edison International believes that a merit-based work environment that includes people with diverse skills, experiences and perspectives is an important driver of success. This merit-based inclusive approach supports a workforce that reflects the customers and communities it serves and enables Edison International to continue to earn public trust and drive better business outcomes. At Edison International, on average, employees in the same role regardless of race/ethnicity or gender identification receive equal pay for equal work. Similar to broader society, when looking at gender or race/ethnicity-specific groups across Edison International without regard to role, female employees and Black and Hispanic employees do not receive comparable pay to male and White employees, respectively, due to lower representation of female, Black and Hispanic employees in higher paying jobs. Edison International is committed to broad recruitment and use of merit-based hiring practices to attract and retain top talent.
 The table below provides Edison International's employee diversity data1 as of December 31, 2024:

 Employees2

 Leaders3

 Executives4

 Females
 %
 %
 %

 Racially/ethnically diverse5

 %
 %
 %

 Racially/ethnically or gender diverse5

 %
 %
 %

 1Calculated using the guidelines SCE uses to calculate the diversity data it reports to the United States Equal Employment Opportunity Commission.
 2Excludes interns and employees on a leave of absence.
 3"Leaders" represents all non-executive manager and supervisor level employees.
 4"Executives" represents all officers and all director level employees.
 5Excludes employees of Trio's subsidiary Alfa Energy Ltd. Alfa Energy Ltd.'s workforce is based in the United Kingdom and does not track race/ethnicity data due to regulatory restrictions.
 To support Edison International's diversity, equity and inclusion efforts, Executives and Leaders are offered training and tools to promote teams that include people with diverse skills, experiences and perspectives. Edison International uses various measures to assess success of its workforce development initiatives, including without limitation, monitoring hiring, promotion and turnover rates.
 Workforce Continuity
 Edison International is committed to identifying and developing the talents of its workforce and takes a variety of steps to increase employee engagement and provide employees opportunities for growth. Employees are offered training

 opportunities, including an onboarding program, technical training, required ethics and compliance training and optional trainings to support career development. SCE estimates that over 95% of active SCE employees completed all assigned training required to be completed in 2024 as part of SCE's enterprise-wide training program. Employees may also be required to take additional trainings based on their job function.
 Employees receive competitive compensation packages which include a wide selection of health plans, a 401(k) savings plan with a company match, wellness programs and initiatives, tuition reimbursement, competitive vacation/holiday program, professional development, volunteer programs, employee assistance program, and a philanthropy and matching contribution program.
 Edison International uses various measures to assess employee engagement and satisfaction, including, without limitation, conducting regular employee engagement surveys and monitoring turnover. Edison International Parent and SCE's combined Turnover Rate was 7.9% and 5.4% in 2024 and 2023, respectively.
 Executives engage in succession planning for leadership positions within the organization. Edison International's and SCE's Boards of Directors also engage in succession planning and talent development discussions for senior officers.
 Edison International's Sustainability Report is available at  The report and any other information contained on, or connected to, this website are not deemed part of, and are not incorporated by reference into, this Annual Report on Form 10-K.

 Insurance
 Edison International maintains a property and casualty insurance program for itself and its subsidiaries and excess liability insurance covering liabilities to third parties for bodily injury or property damage resulting from operations. These policies are subject to specific retentions, sub-limits and deductibles, which are comparable to those carried by other utility companies of similar size. Catastrophic events, such as hurricanes and storms, that have not impacted Edison International or its subsidiaries directly have had an impact, and can have future impacts, on insurance markets overall.
 While SCE maintains insurance relating to cybersecurity events, such insurance is subject to a number of exclusions and may be insufficient to offset any losses, costs or damage experienced.
 SCE also has separate insurance programs for nuclear property and liability, workers compensation and wildfires. For further information on nuclear and wildfire insurance, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies."

 SCE

 Regulation
 CPUC
 The CPUC has the authority to regulate, among other things, retail rates, utility distribution-level equipment and assets, energy purchases on behalf of retail customers, SCE capital structure, rate of return, issuance of securities, disposition of utility assets and facilities, oversight of nuclear decommissioning funding and costs, and aspects of the transmission system planning, site identification and construction, including safety and environmental mitigation. The CPUC can assess penalties on any public utility that violates or fails to comply with its rules and requirements, of up to $100,000, for each offense, which could be assessed daily for a continuing violation. The CPUC's enforcement policy authorizes the staff of the CPUC to draft proposed Administrative Consent Orders and Administrative Enforcement Orders, both of which can include fines and serve as alternatives to issuance of a citation or formal investigation proceeding, for CPUC consideration and approval.
 FERC
 The FERC has the authority to regulate wholesale rates as well as other matters, including unbundled transmission service pricing, rate of return, accounting practices, and licensing of hydroelectric projects. The FERC also has jurisdiction over a portion of the retail rates and associated rate design.
 CAISO
 The CAISO operates a wholesale energy market primarily in California through which competing electricity generators offer their electricity output to market participants, including electricity retailers. SCE has placed its transmission system under the operational control of the CAISO.

 Major transmission projects required for reliability, economic and other policy reasons are identified and approved through the CAISO's annual transmission planning process. Depending on the nature of the project identified, it may be assigned to SCE or set for competitive bid.
 The CAISO is conducting transmission planning studies to identify transmission needed to meet a 30 million metric ton GHG emissions target by 2030 set by the CPUC for California's electricity sector to support California's target of reducing overall GHG emissions statewide.
 NERC
 The FERC assigned administrative responsibility to the NERC to establish and enforce reliability standards and critical infrastructure protection standards, which protect the bulk power system against potential disruptions from cyber and physical security breaches. The critical infrastructure protection standards focus on controlling access to critical physical and cybersecurity assets, including supervisory control and data acquisition systems for the electric grid. The reliability standards define the requirements for planning and operating the bulk power system. Compliance with these standards is mandatory. As of the date of this filing, the maximum penalty that may be levied for violating a NERC reliability or critical infrastructure protection standard is approximately $1.5 million per violation, per day.
 OEIS
 Effective July 1, 2021, the OEIS became the successor to the CPUC's Wildfire Safety Division ("WSD"), and was vested with the powers, duties, and responsibilities of the WSD, as well as other statutory authority. OEIS is responsible for, among other things, approving and overseeing compliance with WMPs. As part of overseeing WMP compliance, OEIS can issue notices of violation and recommend that the Commission pursue an enforcement action against an electrical corporation for noncompliance with its approved WMP. Other OEIS tasks include conducting safety culture assessments, approving executive compensation structures, and issuing safety certifications.
 NRC
 The NRC has jurisdiction with respect to the safety of San Onofre and Palo Verde Nuclear Generating Stations. The NRC regulates commercial nuclear power plants through licensing, oversight and inspection, performance assessment, and enforcement of its requirements. In June 2013, SCE decided to permanently retire and decommission San Onofre. The NRC regulates the decommissioning of San Onofre. For further information, see "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" in the MD&A.
 Other Regulatory Agencies
 The construction, planning and project site identification of SCE's transmission lines and substation facilities require compliance with various laws and approval of many governmental agencies in addition to the CPUC and FERC. These include various state regulatory agencies depending on the project location; the U.S. Environmental Protection Agency and other environmental, land management and resource agencies such as the Bureau of Land Management, the U.S. Forest Service, the California Department of Fish and Wildlife, the California Coastal Commission, and the State Water Resources Control Board. In addition, to the extent that SCE transmission line projects pass through lands owned or controlled by Native American tribes, consent and approval from the affected tribes and the Bureau of Indian Affairs are also necessary for the project to proceed.
 Compliance with Government Regulations
 SCE incurs significant costs to comply with government regulations. These costs, which include operation and maintenance expenses and capital expenses, include without limitation: costs incurred to maintain wildfire insurance coverage required under AB 1054; comply with environmental regulations, including licensing requirements, regulations governing California's renewable energy standards and regulations governing the decommissioning of San Onofre; land use and construction regulations; privacy and cybersecurity regulations; and Occupational Safety and Health Administration regulations. SCE also incurs operation and maintenance expenses and capital expenses to comply with requirements set forth in various regulatory decisions, including costs incurred to implement its approved capital projects and safety programs such as its WMPs.
 Most costs incurred by SCE to comply with government regulations are authorized in its CPUC and FERC general rate cases and, are therefore, recovered through electric rates. To the extent SCE incurs costs to comply with government regulations above those that are authorized, or prior to obtaining authorization for recovery through rates (for instance certain costs incurred in line with SCE's obligations under its WMPs and tracked in wildfire mitigation-related memorandum accounts), SCE will seek recovery of such costs through electric rates to the extent they are eligible for recovery. There is no assurance that SCE will be allowed to fully recover these costs. For further information on wildfire

 mitigation and wildfire insurance costs, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings."
 SCE earns a rate of return on its authorized capital expenditures included in its rate base. Approximately $1.6 billion of spending by SCE on wildfire risk mitigation capital expenditures made after August 1, 2019 are not included in rate base under the terms of AB 1054.

 Overview of Ratemaking Process
 CPUC
 Revenue authorized by the CPUC through GRC proceedings is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investments in generation and distribution assets and general plant (also referred to as "rate base") on a forecast basis. Revenue is authorized through quadrennial GRC proceedings where the CPUC sets an annual revenue requirement for the base year which is made up of the operation and maintenance costs, depreciation, taxes and a return consistent with the authorized cost of capital (discussed below). In the GRC proceedings, the CPUC also generally approves the level of capital spending on a forecast basis. Following the base year, the revenue requirements for the remaining three years will be set by a methodology established in the GRC proceeding, which has generally, among other items, included annual allowances for escalation in operation and maintenance costs and additional changes in capital-related investments.
 SCE's 2021 GRC authorized revenue requirements for 2021, 2022, 2023 and 2024 of $6.9 billion, $7.3 billion, $7.7 billion and $8.4 billion, with the approved revenue requirement for 2024 being subject to adjustments for SCE's 2024 cost of capital and expanded customer-funded self-insurance for wildfire-related claims. In May 2023, SCE filed its 2025 GRC application for the four-year period of 2025 – 2028. For further discussion of the 2025 GRC, see "Management Overview – 2025 General Rate Case" in the MD&A.
 By May 15 in the year preceding each GRC application filing date, SCE is required to file a Risk Assessment and Mitigation Phase ("RAMP") application with the CPUC to provide information about SCE's assessment of its key safety risks and its proposed programs and spending for mitigating those risks. SCE filed its RAMP application for the 2025 GRC in May 2022. The information developed during the RAMP informs SCE's proposed projects and funding requests in the subsequent phase of the GRC.
 The CPUC regulates SCE's cost of capital, including its capital structure and authorized rates of return. SCE's currently authorized capital structure is 43% long-term debt, 5% preferred equity and 52% common equity. SCE's authorized capital structure is subject to certain exclusions, for example the waiver of certain expenses and debt related to the 2017/2018 Wildfire/Mudslide Events. For further information on the exclusion related to the 2017/2018 Wildfire/Mudslide Events, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."
 SCE's currently authorized cost of capital for 2025 consists of: cost of long-term debt of 4.58%, cost of preferred equity of 6.42% and ROE of 10.33%. Based on these cost factors and the capital structure discussed above, SCE's weighted average return on rate base will be 7.66% for 2025.
 CPUC rates decouple authorized revenue from the volume of electricity sales so that SCE receives revenue equal to amounts authorized. Differences between amounts collected and authorized levels are either collected from or refunded to customers, and, therefore, such differences do not impact operating revenue. Accordingly, SCE is neither benefited nor burdened by the volume of retail electricity sales.
 Cost-recovery balancing accounts track the difference between actual expenditures associated with the account, revenue authorized for recovery by the CPUC (authorized revenue requirement), and the actual revenues collected within customer rates to cover those specific expenditures. These balancing accounts are used to track and recover, among other things, SCE's decoupled costs of fuel and purchased power, as well as certain operation and maintenance expenses. SCE earns no return on these activities and although differences between forecasted and actual costs do not impact earnings, such differences do impact cash flows and can change rapidly. SCE also has capital-related balancing accounts on which it earns a return, such as the pole loading balancing account. Costs tracked in balancing accounts are not subject to after-the-fact reasonableness review unless the balancing accounts are one-way balancing accounts or otherwise subject to a cost cap. SCE also has memorandum accounts, which track costs above authorized levels eligible for cost recovery upon a future reasonableness review. To the extent SCE does not have a tracking mechanism, SCE cannot recover expenses that exceed authorized amounts. However, every subsequent GRC allows SCE to reflect its prior actual investment in plant as a part of the forecast for the next test year.
 Under the 2021 GRC final decision, SCE can recover WCCP expenditures up to 110% of authorized WCCP amounts and up to 115% of authorized vegetation management expenses without being subject to after-the fact reasonableness review. SCE can seek recovery of WCCP amounts above 110% of authorized levels and vegetation management expenses above

 115% of authorized levels through reasonableness review applications. "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings—2021 GRC Wildfire Mitigation Memorandum Account Balances."
 SCE's cost-recovery mechanism for its fuel and purchased power-related costs is facilitated in three main balancing accounts, the ERRA, the PABA, and the new system generation balancing account ("NSGBA"). For all three accounts, SCE sets rates based on an annual forecast of the costs that it expects to incur during the subsequent year. In addition, the CPUC has established a "trigger" mechanism for the ERRA and the PABA. The trigger mechanism requires SCE to request an expeditious rate change if the sum of the ERRA balance and the bundled service customers' pro-rata share of the PABA balance exceeds 4% of SCE's prior year generation rate revenue and SCE does not expect the aggregate overcollection or undercollection to fall below 5% of SCE's prior year generation rate revenue within 120 days. For 2025, SCE estimates the 4% and 5% trigger amounts to be approximately $234 million and $292 million, respectively.
 For 2024, the 4% and 5% trigger amounts were approximately $258 million and $323 million, respectively. As of December 31, 2024, the ERRA was overcollected by approximately $854 million, the PABA was undercollected by approximately $800 million, and the NSGBA was undercollected by approximately $54 million. In December 2024, the CPUC approved SCE incorporating these year-end balances into customer rates in January 2025.
 The majority of fuel and purchased power procurement-related costs eligible for recovery through cost-recovery rates are pre-approved by the CPUC through specific decisions and a procurement plan with predefined standards that establish the eligibility for cost-recovery. If such costs are subsequently found to be non-compliant with this procurement plan, then this could negatively impact SCE's earnings and cash flows. In addition, the CPUC retrospectively reviews outages associated with utility-owned generation and SCE's power procurement contract administration activities through the annual ERRA review proceeding. A CPUC finding that SCE was unreasonable or imprudent with respect to its utility-owned generation outages and contract administration activities, could negatively impact SCE's earnings and cash flows. The ERRA review proceeding is also used as a venue to review costs in various memorandum and balancing accounts including the Pole Loading and Deteriorated Pole Programs Balancing Account.
 A California law adopted in 2022 has directed the CPUC to develop a definition of energy affordability and to use energy affordability metrics to guide the development of any protections, incentives, discounts, or new programs to assist residential customers facing hardships or disconnections due to electricity or gas bills and to assess the impact of proposed rate increases on different types of residential customers.
 FERC
 Transmission capital and operating costs that are prudently incurred, including a return on its net investment in transmission assets, are recovered through revenue authorized by the FERC. Since 2012, SCE has used a formula rate to determine SCE's FERC transmission revenue requirement, including its construction work in progress (CWIP) revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. The transmission revenue requirement and rates are updated each December, to reflect a forecast of costs for the upcoming rate period, as well as a true up of the transmission revenue to actual costs incurred by SCE in the prior calendar year on its formula rate.
 The FERC ROE is currently fixed at 10.3% and does not separately reflect any adders. The FERC ROE would only change if a different ROE is approved by the FERC in a new proceeding. For further information on the FERC formula rates, related transmission revenue requirements and rate changes, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings—2025 FERC Formula Rate Annual Update" in the MD&A.
 Retail Rates Structure and Residential Rate Design
 To develop retail rates, the authorized revenue requirements are allocated among all customer classes (residential, commercial, industrial, agricultural and street lighting) on a functional basis (i.e., generation, distribution, transmission, etc.). Specific rate components are designed to recover the authorized revenue allocated to each customer class.
 SCE has a two-tier residential rate structure. The first tier is priced below the average rate and is intended to cover the customer's essential electricity needs. The second tier is priced at 29% more than the first tier. The CPUC has ordered a transition from tiered to time-of-use ("TOU") rates for most residential customers unless they opt to stay on the tiered rate structure. The TOU rate structure is the current default rate and also incorporates the two-tier structure through a baseline credit applied to approximately 300 kWh a month. Under a TOU rate structure, rates are based on the time of day and the season. TOU rates are typically lower early in the day, overnight, and on the weekends when energy resources are less in demand. SCE completed a multi-year transition to TOU rates in June 2022, and, as of December 31, 2024, approximately 60% of residential customers are on TOU rates. To recover a portion of the fixed costs of serving no- or low-usage residential customers, SCE assesses both fixed charges of less than $1 per month, and a minimum charge of $10 per month ($5 for low-income customers). In May 2024, the CPUC authorized a residential class Basic Service Charge (i.e., fixed

 charge) with three tier level graduations. The Basic Service Charge graduations are based on participation in income-qualified programs. Customers in the California Alternative Rates for Energy (CARE) and Family Electric Rates Assistance (FERA) programs receive Basic Service Charges that are respectively 25% and 50% of the $24.15 fixed charge applicable to all other residential customers. The newly adopted fixed charges will be implemented in the fourth quarter of 2025. SCE will continue to offer financial assistance programs (CARE and FERA) that provide significant discounts to customers who qualify for bill assistance based on their household size and income. For information on residential rates for customers with renewable generation systems, see "—Competition" below.

 Purchased Power and Fuel Supply
 SCE obtains the power, energy, and local grid support needed to serve its customers primarily from purchases from external parties. SCE estimates that approximately 19% of power delivered to SCE's customers in 2024 came from SCE's own generating facilities.
 Natural Gas Supply
 SCE requires natural gas to fuel its Mountainview and peaker plants, which are generation units that operate in response to wholesale market signals related to power prices and reliability needs. The physical natural gas purchased by SCE is sourced in competitive interstate markets at trading points on the SoCalGas local distribution company system. SoCalGas is the primary provider of intrastate pipeline transportation service to the gas-fueled generation stations that SCE controls. In 2015 – 2016, SoCalGas experienced a significant natural gas fuel leak at its Aliso Canyon underground gas storage facility that resulted in reduced capacity and usage of the facility. Currently, Aliso Canyon is authorized to operate at up to 79% of its maximum capacity. CPUC has established a biennial assessment process to evaluate the reliability and cost impacts of minimizing or eliminating reliance on Aliso Canyon. To date, SCE has found that gas storage-use restrictions combined with SoCalGas pipeline maintenance constraints contributed to increased electricity costs for customers but did not impact grid reliability. However, there is no certainty that these restrictions or pipeline constraints will not impact grid reliability in the future. Price increases faced by customers would not affect SCE's earnings because SCE expects recovery of these costs through the ERRA balancing account or other CPUC approved procurement plans. However, these higher prices may impact cash flow due to the timing of those recoveries. For more information on cost-recovery mechanisms, see "—Overview of Ratemaking Process" above. SCE is actively monitoring legislative and regulatory processes that are addressing pipeline and electric grid operations impacted by the Aliso Canyon leak, including an Order Instituting Investigation issued by the CPUC in February 2017 to consider the feasibility of minimizing or eliminating the use of the Aliso Canyon facility. SCE has also made additional procurement efforts to alleviate the impact of the partial closure of Aliso Canyon, including accelerating existing contracts for new capacity, procuring energy storage from third-parties, contracting for design, build, and transfer of utility-owned storage, procuring additional demand response and contracting for firm gas transportation capacity.
 CAISO Wholesale Energy Market
 The CAISO operates a wholesale energy market primarily in California through which competing electricity generators offer their electricity output to market participants, including electricity retailers. The CAISO schedules power in hourly increments with hourly prices through a day-ahead market in California and schedules power in fifteen-minute and five-minute increments with fifteen-minute and five-minute prices through two real-time markets that cover California and portions of ten neighboring states through the Western Energy Imbalance Market. Both markets optimize energy procurement, ancillary service procurement, unit commitment and congestion management. SCE participates in the day-ahead and real-time markets for the sale of its own generation and generation under contract and for purchases for its load requirements. In December 2023, the FERC approved an Extended Day-Ahead Market ("EDAM"), giving utilities in the Western Energy Imbalance Market the option of joining a centralized day-ahead market run by the CAISO. The EDAM gives utilities an opportunity to lock in energy prices a day in advance, and thereby substantially avoid volatility in the real-time energy market.
 The CPUC's Resource Adequacy program imposes resource adequacy requirements on load-serving entities like SCE that are designed to provide sufficient resources to the CAISO to ensure the safe and reliable operation of the grid in real time. The CPUC has adopted a central procurement structure in SCE's distribution service area for local resource adequacy that transfers the responsibility for procuring local resource adequacy from other local load-serving entities to SCE as a central procurement entity ("CPE") for its distribution service area. Under this structure, while SCE procures local resource adequacy to meet the local resource adequacy requirement for its distribution service area, other load-serving entities can also procure their own local resources. Load-serving entities that procure their own local resources can: (i) sell the capacity to SCE, (ii) utilize the resources, or (iii) voluntarily show the resources to meet their own needs, thereby reducing the amount of local resource adequacy the CPE will need to procure and reducing the total CPE procurement costs shared by all load-serving entities in that distribution service area.

 Following state-wide rotating outages in August 2020 that impacted a significant number of SCE's customers, the CPUC has taken action towards ensuring reliable electric service in the event that an extreme heat events occur during summer. The CPUC has issued decisions requiring at least an aggregate of 15,500 MW of additional net qualifying renewable or zero-emitting capacity to be procured collectively by all of the load-serving entities subject to the CPUC's Integrated Resource Planning purview. The aggregate additional capacity is required by 2028, with 2,000 MW required by 2023, an additional 6,000 MW required by 2024, an additional 1,500 MW required by 2025, an additional 2,000 MW required by 2026, an additional 2,000 MW required by 2027, and an additional 2,000 MW of long-lead time resources, comprised of 1,000 MW of long-duration storage and 1,000 MW of firm zero-emitting resources required by 2028; 2,500 MW of the aggregate procurement requirement through 2025 must be through generation or generation paired with storage.
 SCE's allocation of the requirements is 705 MW by 2023, 2,114 MW by 2024, 529 MW by 2025, 684 MW by 2026, 684 MW by 2027, and 705 MW of long-lead time resources, comprised of 353 MW of long-duration storage and 352 MW of firm zero-emitting resources by 2028, for a total of 5,421 MW; 880 MW of the aggregate procurement requirement through 2025 must be through generation or generation paired with storage.
 SCE has met its capacity requirements through 2027, and its long-duration storage requirement for 2028. SCE expects to meet its firm zero-emitting requirement in the first quarter of 2025, which will fully satisfy SCE's overall procurement requirements. As of December 31, 2024, SCE had procured approximately 5,583 MW of additional qualifying renewable or zero-emitting capacity with expected online dates in 2023 through 2028; approximately 1,900 MW of this capacity has come online. SCE has procured approximately 658 MW (and expects to have 729 MW, fully meeting the requirements, in the first quarter of 2025) of qualifying capacity with expected online dates by 2028 toward the long-duration storage and firm-zero emitting resource procurement requirements. SCE has procured the capacity and generation needed to meet its 880 MW aggregate procurement requirement for generation or generation paired with storage by 2025, but some of that generation is not expected to come online until 2026 and 2027. In September 2024, the CPUC issued a decision allowing temporary zero-emitting or RPS-eligible incremental bridge resources to meet the 2025 procurement requirement for generation or generation paired with storage. This allows SCE to use certain temporary bridge resources for up to three years to meet its 880 MW procurement requirement for generation or generation paired with storage by 2025, until its contracted resources expected to come online in 2026 and 2027 are online. SCE has procured sufficient temporary bridge resources to meet the 880 MW procurement requirement by 2025 until its other contracted resources come online in 2026 and 2027.
 In February 2024, the CPUC adopted a decision approving SCE's integrated resource plan identifying the resources needed to meet California's greenhouse gas emissions and reliability targets and authorizing SCE to procure the resource needs identified in its plan. Additionally, the CPUC approved a process to request extensions of the 2028 procurement requirement for long-duration storage and firm zero-emitting resources to no later than 2031. The CPUC also denied SCE's request for extension of the 2025 aggregate procurement requirement for generation or generation paired with storage to 2027, although a subsequent decision issued in September 2024 allowed temporary zero-emitting or RPS-eligible bridge resources to meet the requirement as discussed above.

 Competition
 SCE faces retail competition in the sale of electricity to the extent that federal and California laws permit other sources to provide electricity and related services to retail customers within SCE's service area. While retail competition impacts customer rates it does not impact SCE's earnings activities because the volume of electricity sales is decoupled from authorized revenue. The increased retail competition is from governmental entities formed by cities, counties, and certain other public agencies to generate and/or purchase electricity for their local residents and businesses, known as CCAs. While California law provides only limited opportunities for customers in SCE's service area to choose to purchase power directly from an Electric Service Provider, a limited, phased-in expansion of customer choice ("Direct Access") for nonresidential customers was authorized beginning in 2009, and an additional limited expansion of Direct Access was authorized in 2018. When a customer who had previously taken bundled service from SCE converts to taking retail electricity service from an Electric Service Provider or a CCA, SCE remains that customer's transmission and distribution provider. Other forms of departing load include customer generation, and load that departs SCE service entirely to take electricity service from a publicly owned utility or a tribal utility.
 California law requires bundled service customers to remain financially indifferent to departing load customers and to the mass return of departing load customers in the event of an Electric Service Provider or CCA's failure or other service termination. The CPUC has issued a series of decisions designed to avoid cost shifting in the context of departing load, including revising the power charge indifference adjustment methodology to effectively address the cost shifts to bundled service customers.
 Investor-owned utilities serve as the default providers of last resort in their respective service areas and can be significantly impacted by the Electric Service Providers or CCAs failing or otherwise exiting the market. In March 2021, the CPUC initiated a rulemaking to examine the risks of catastrophic failures by Electric Service Providers or CCAs on investor-

 owned utilities and the need for any changes in the regulatory framework to increase consumer protections and financial security requirements, among other measures. As part of this rulemaking, the CPUC will also examine under what requirements a CCA or Electric Service Provider may assume the provider of last resort obligation from an investor-owned electric utility in some or all of the utility's service area.
 As of year-end 2024, SCE had twelve CCAs serving customers in its service area that represented approximately 21% of SCE's total service load. While one CCA terminated service and mass returned its customers to SCE's bundled service in 2024, one CCA expanded in SCE's service area in 2024 and two CCAs expanded in SCE's service area in 2023. One expanded CCA has been approved by the CPUC to serve customers in SCE's service area in 2025. Based on recent load statistics, SCE anticipates that Direct Access and CCA load will be approximately 16% and 21% of its total service load by the end of 2025, respectively.
 Customer-owned power generation and storage alternatives, such as rooftop solar facilities and battery systems, are increasingly installed by SCE's customers behind SCE's revenue meter as a result of technological developments, federal and state subsidies, and declining costs of such alternatives. Beginning in 2020, and subject to certain exceptions, most newly built homes in California are required to have solar installations.
 California legislation passed in 1995 encouraged private residential and commercial investment in renewable energy resources by requiring SCE and other investor-owned electric utilities to offer a NEM billing option to customers who install eligible power generation systems to supply all or part of their energy needs. NEM customers are interconnected to SCE's grid and credited for the net difference between the electricity SCE supplied to them through the grid and the electricity the customer exported to SCE over a 12-month period. SCE is required to credit the NEM customer for most of the power they sell back to SCE at the retail rate. Through the credit they receive, NEM customers effectively avoid paying certain grid-related costs. NEM customers are also exempted from some non-bypassable, standby and departing load charges and interconnection fees. Electric Service Providers and CCAs may, but are not required by law to, offer NEM rates.
 In January 2016, the CPUC issued a decision adopting a new standard NEM tariff for customers with renewable generation systems. The changes that the CPUC decision made to the existing NEM tariff did not significantly impact the NEM subsidy. Specifically, the decision required customers that take service on SCE's NEM tariff after June 2017 to continue to be compensated at the retail rate, minus certain non-bypassable charges. NEM customers also continued to be exempted from standby and departing load charges but were required to pay a $75 interconnection fee and to select a time-of-use retail rate.
 In August 2020, the CPUC initiated a rulemaking to develop a successor to the NEM tariffs. In December 2022, the CPUC issued a final decision adopting a Net Billing Tariff (NBT) that decoupled export compensation from the retail rate, which lowers the subsidy compared to NEM. Under the final decision, the CPUC deferred consideration of whether to assess a grid participation charge to address the costs participating customers avoid by reducing the electricity they purchase from SCE and whether to adopt other mechanisms that would allow SCE to recover its cost of service and the costs of many public policy programs to another pending proceeding. The final decision also provides an enhanced subsidy for lower income customers and customers who pair rooftop solar with energy storage systems. The final decision does not apply to existing NEM customers until after they have completed twenty years on their existing NEM tariff, at which time they will move to the new, reduced NBT tariff.
 The effect of these types of competition on SCE generally is to reduce the amount of electricity purchased from SCE by retail customers. Customers who use alternative electricity sources typically continue to use and pay for SCE's transmission and distribution services; however, current NEM customers use, but do not pay the full cost for, those services. While changes in volume or rates generally do not impact SCE's earnings activities, decreased retail electricity sales by SCE has the effect of increasing utility rates because the costs of the distribution grid are not currently borne by all customers that benefit from its use. However, in a recent Decision, issued in May of 2024, the CPUC authorized a Base Service Charge for all residential rates, which will be implemented starting in late 2025. The Base Service Charge recovers a portion of the fixed costs of providing service. See "Risk Factors—Risks Relating to Southern California Edison Company—Competitive and Market Risks."
 In the area of transmission infrastructure, SCE has experienced increased competition from independent transmission providers under the FERC's transmission planning requirements rules, effective in 2011, that removed the incumbent public utility transmission owners' federally-based right of first refusal to construct certain new transmission facilities and mandated regional and interregional transmission planning. Regional entities, such as independent system operators, have processes for regional and interregional transmission planning and the competitive solicitation and selection of developers (including incumbent utilities) to build and own certain types of new transmission projects. The CAISO has held competitive solicitations pursuant to these rules and independent service providers were selected.

 Properties
 SCE supplies electricity to its customers through extensive transmission and distribution networks. Its transmission facilities, which are located primarily in California but also in Nevada and Arizona, deliver power from generating sources to the distribution network and consist of approximately 13,000 circuit-miles of lines ranging from 55 kV to 500 kV and approximately 80 transmission substations. SCE's distribution system, which takes power from distribution substations to customers, consists of approximately 38,000 circuit-miles of overhead lines, approximately 32,000 circuit-miles of underground lines and approximately 730 distribution substations.
 At December 31, 2024, SCE had ownership interests in generating and energy storage facilities, primarily located in California, with approximately 7,000 MW of net physical capacity, of which SCE's pro-rata share is approximately 3,500 MW. SCE's pro rata share includes approximately 63 MW of capacity from facilities that were not operational or out of service at December 31, 2024 and excludes retired facilities. In addition, SCE owns two utility storage facilities in SCE's service area with an aggregate capacity of 312.5 MW and a third 225 MW facility is expected to be in-service in 2025. See "Liquidity and Capital Resources—Capital Investment Plan—Utility Owned Storage Projects " in the MD&A.
 Certain of SCE's substations, and portions of its transmission, distribution and communication systems are located on lands owned by the federal, state or local governments under licenses, permits, easements or leases, or on public streets or highways pursuant to franchises. Certain of the documents evidencing such rights obligate SCE, under specified circumstances and at its expense, to relocate such transmission, distribution, and communication facilities located on lands owned or controlled by federal, state, or local governments.
 SCE owns and operates hydroelectric plants and related reservoirs, the majority of which are located in whole or in part on U.S.-owned lands and are subject to FERC licenses. Slightly over half of these plants have FERC licenses that expire at various times through 2046. FERC licenses impose numerous restrictions and obligations on SCE, including the right of the United States to acquire projects upon payment of specified compensation. When existing licenses expire, the FERC has the authority to issue new licenses to third parties that have filed competing license applications, but only if their license application is superior to SCE's and then only upon payment of specified compensation to SCE. New licenses issued to SCE are expected to contain more restrictions and obligations than the expired licenses because laws enacted since the existing licenses were issued require the FERC to give environmental objectives greater consideration in the licensing process. In addition, SCE expects additional opposition to new licenses by environmental stakeholder groups. If, in the future, SCE decides to, or is forced to, decommission one or more hydroelectric projects, the costs related to the decommissioning will be substantial. The CPUC approved SCE recovering a portion of estimated decommissioning costs for hydroelectric projects in the 2021 GRC. SCE intends to sell, subject to regulatory approval, a portion of its hydroelectric facilities comprising of approximately 17 MW of capacity by 2027.
 Substantially all of SCE's properties are subject to the lien of a trust indenture securing first and refunding mortgage bonds. See "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."

 Seasonality
 Due to warm weather during the summer months and SCE's rate design, operating revenue during the third quarter of each year is generally higher than the other quarters. However, as discussed above, SCE earnings are not affected by changes in retail electricity sales. See "Overview of Ratemaking Process" above.

 SOUTHERN CALIFORNIA WILDFIRES
 Unprecedented weather conditions in California due to climate change have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area, including as recently as January 2025. Multiple factors have contributed to increased wildfire activity and faster progression of wildfires across SCE's service area and in other areas of California in recent years. These include the buildup of dry vegetation in areas severely impacted by years of historic drought, lack of adequate clearing of hazardous fuels by responsible parties, higher temperatures, lower humidity, increased incidence of dry lightning, and strong Santa Ana winds. At the same time that wildfire risk has been increasing in Southern California, residential and commercial development has occurred and is occurring in some of the highest-risk areas. Such factors can increase the likelihood and extent of damage caused by wildfires. SCE has determined that approximately 27% of its service area is in areas identified as high fire risk, and SCE's service area remains susceptible to additional wildfire activity.
 In response to worsening conditions and wildfire activity in its service area, SCE has been, and will continue to be, focused on developing and implementing plans aimed at reducing the risk of SCE equipment contributing to the ignition of wildfires. In addition, California must also continue to increase its investment in wildfire prevention and fire suppression capabilities.

 Multiple lawsuits related to wildfire events have been initiated against SCE and Edison International. For further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides," "Risk Factors" and "Management Overview—Southern California Wildfires and Mudslides" in the MD&A.

 Recovery of Wildfire-Related Costs
 Pre-AB 1054 Cost Recovery
 California courts have previously found investor-owned utilities to be strictly liable for property damage, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. The rationale stated by these courts for applying this theory to investor-owned utilities is that property damages resulting from a public improvement, such as the distribution of electricity, can be spread across the larger community that benefited from such improvement through recovery of uninsured wildfire-related costs in electric rates. However, in November 2017, the CPUC issued a decision denying SDG&E's request to include in its rates uninsured wildfire-related costs arising from several 2007 wildfires, finding that SDG&E did not meet the prudency standard because it did not prudently manage and operate its facilities prior to or at the outset of the 2007 wildfires. In July 2018, the CPUC denied both SDG&E's application for rehearing on its cost recovery request and a joint application for rehearing filed by SCE and PG&E limited to the applicability of inverse condemnation principles in the same proceeding. The California Court of Appeal, the California Supreme Court and the United States Supreme Court denied SDG&E's petitions for review of the CPUC's denial of SDG&E's application.
 2019 Wildfire Legislation
 In July 2019, AB 1054 was signed by the Governor of California and became effective immediately. In addition to a revised prudency standard, AB 1054 provided for the Wildfire Insurance Fund for the benefit of the three California investor-owned utilities participating in the fund, PG&E, SCE and SDG&E. The summary of the wildfire legislation below and elsewhere within this report is based on SCE's interpretation of AB 1054.
 AB 1054 Prudency Standard
 Under AB 1054, the CPUC must apply a revised framework when assessing the prudency of a utility in connection with a request for recovery of wildfire costs for wildfires ignited after July 12, 2019. Under AB 1054, the CPUC is required to find a utility to be prudent if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken under similar circumstances, at the relevant point in time, and based on the information available at that time. Prudent conduct under the AB 1054 standard is not limited to the optimum practice, method, or act to the exclusion of others, but rather encompasses a spectrum of possible practices, methods, or acts consistent with utility system needs, the interest of ratepayers, and the requirements of governmental agencies. AB 1054 also clarifies that the CPUC may determine that wildfire costs may be recoverable, in whole or in part, by taking into account factors within and outside the utility's control, including humidity, temperature, and winds. Further, utilities with a valid safety certification will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates serious doubt as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to prove its conduct was prudent. If a utility does not have a valid safety certification, it will have the burden to prove, based on a preponderance of evidence, that its conduct was prudent. The new prudency framework will survive the termination of the Wildfire Insurance Fund.
 Utilities participating in the Wildfire Insurance Fund that are found to be prudent are not required to reimburse the fund for amounts withdrawn from the fund. Participating utilities can request recovery of wildfire costs through electric rates if the fund has been exhausted.
 Wildfire Insurance Fund
 AB 1054 provided for the Wildfire Insurance Fund to reimburse a participating utility for payment of third-party damages claims arising from certain wildfires that exceed, in aggregate in a calendar year, the greater of $1.0 billion or the insurance coverage required to be maintained under AB 1054. The Wildfire Insurance Fund was established in September 2019 and is available for claims related to wildfires ignited after July 12, 2019 that are determined by the responsible government investigatory agency or a court to have been caused by a utility or are asserted to have been caused by a utility and result in a court-approved dismissal resulting from the settlement of third-party damage claims.
 SCE and SDG&E collectively made their initial contributions totaling approximately $2.7 billion (SCE share is $2.4 billion) to the Wildfire Insurance Fund in September 2019. Upon its emergence from bankruptcy, on July 1, 2020, PG&E made its initial contribution of approximately $4.8 billion to the Wildfire Insurance Fund. PG&E, SCE and SDG&E are also collectively expected to make aggregate contributions of approximately $3.0 billion (SCE share is $950 million) to the Wildfire Insurance Fund through annual contributions to the fund over a 10-year period by no later than January 1 of

 each year, of which they have made six annual contributions totaling approximately $1.8 billion (SCE share is approximately $570 million). In addition to PG&E's, SCE's and SDG&E's contributions to the Wildfire Insurance Fund, PG&E, SCE and SDG&E are expected to collect $6.1 billion, $6.1 billion and $1.3 billion, respectively, from their customers over a 15-year period through a dedicated rate component. The amount collected from customers may be directly contributed to the Wildfire Insurance Fund or used to support the issuance of up to $10.5 billion in bonds by the California Department of Water Resources, the proceeds of which would be contributed to the fund. In addition to funding contributions to the Wildfire Insurance Fund, the amount collected from utility customers will pay for, among other things, any interest and financing costs related to any bonds that are issued by the California Department of Water Resources to support the contributions to the Wildfire Insurance Fund.
 SCE's contributions to the Wildfire Insurance Fund are not recoverable through electric rates and will be excluded from the measurement of SCE's CPUC-jurisdictional authorized capital structure. SCE will also not be entitled to cost recovery for any borrowing costs incurred in connection with its contributions to the Wildfire Insurance Fund. For information on the accounting impact of SCE's contributions to the Wildfire Insurance Fund see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Initial and annual contributions to the wildfire insurance fund established pursuant to California Assembly Bill 1054 " in this report.
 Reimbursement from Wildfire Insurance Fund and AB 1054 Liability Cap
 Until the fund administrator determines that the fund will be terminated, participating investor-owned utilities are expected to be reimbursed from the Wildfire Insurance Fund for eligible claims, on a first come, first served basis, subject to the fund administrator's review. SCE will reimburse the fund for any withdrawn amounts if SCE receives payment of such amounts under an indemnification agreement or from an insurance provider or other third-party. SCE will also be required to reimburse the fund for withdrawn amounts that the CPUC disallows, subject to the AB 1054 Liability Cap. If the utility has maintained a valid safety certification and its actions or inactions that resulted in the wildfire are not found to constitute conscious or willful disregard of the rights and safety of others, the aggregate requirement to reimburse the fund over a trailing three calendar year period is capped at 20% of the equity portion of the utility's transmission and distribution rate base in the year of the prudency determination. Based on SCE's weighted-average 2024 transmission and distribution rate base, excluding general plant and intangibles, and using the equity portion of SCE's CPUC authorized capital structure of 52%, SCE's requirement to reimburse the Wildfire Insurance Fund for amounts disallowed in 2024 would have been capped at approximately $3.9 billion. SCE will calculate the AB 1054 Liability Cap for amounts disallowed in 2025 after a final decision in the 2025 GRC is approved.
 SCE will not be allowed to recover borrowing costs incurred to reimburse the fund for amounts that the CPUC disallows. The Wildfire Insurance Fund and, consequently, the AB 1054 Liability Cap will terminate when the administrator determines that the fund has been exhausted.

 Safety Certification and Wildfire Mitigation Plan
 Under AB 1054, SCE can obtain an annual safety certification upon approval by OEIS of certain requirements, including an approved WMP. Under AB 1054, SCE is also required to submit a comprehensive WMP to the CPUC at least once every three years for review and approval. Each such comprehensive plan is required to cover at least a three-year period. In addition, SCE anticipates updating its comprehensive three-year plans annually in the intervening years.
 SCE submitted its 2023 – 2025 WMP in March 2023. The OEIS approved SCE's 2023 – 2025 WMP in October 2023 and the CPUC ratified the OEIS approval in November 2023. The OEIS approved SCE's 2025 WMP update in October 2024 and the CPUC ratified the OEIS approval in January 2025.
 On December 11, 2024, OEIS issued SCE's safety certification, which will be valid for 12 months from the date of issuance. Notwithstanding its 12-month term, if SCE requests a new safety certification by September 12, 2025, then its current safety certification will remain valid until OEIS acts on SCE's request.

 Public Safety Power Shutoffs
 In addition to the investments SCE is making as part of its WMP, SCE also uses Public Safety Power Shutoffs ("PSPS") to proactively de-energize power lines as a last resort to mitigate the risk of catastrophic wildfires during extreme weather events.
 SCE initiated PSPS 12 times in 2020 as part of its wildfire mitigation efforts resulting in an aggregate of approximately 268 million customer minutes interrupted. Since 2020, on a risk informed basis, SCE has made and continues to make significant investments and progress in improving its PSPS protocols. SCE initiated PSPS 21 times in 2024 resulting in approximately 224 million customer minutes interrupted. As of February 20, 2025, SCE initiated PSPS two times in 2025 resulting in approximately one billion customer minutes interrupted primarily in Los Angeles, Riverside, San Bernardino, and Ventura counties under conditions of severe windstorm events.

 In June 2021, the CPUC issued a final decision which, among other things, will reduce future authorized revenue for the volumetric reductions in electricity sales resulting from PSPS events initiated after June 2021 until the CPUC determines that improvements in the PSPS program have been made.
 In June 2022, the SED issued an Administrative Enforcement Order ("AEO") against SCE proposing penalties of $10 million for alleged noncompliance with customer notification requirements related to PSPS events in 2020. In October 2022, the SED and SCE reached a settlement agreement under which SCE agreed to a penalty of $7 million, inclusive of a $6 million disallowance of PSPS program-related costs. SCE also agreed to complete certain corrective actions to resolve the AEO. SCE certified completion of the AEO corrective actions in June 2023. SCE did not admit wrongdoing or liability as part of the settlement. SCE's obligations under the settlement agreement commenced in August 2023 when CPUC approval of the agreement became final and non-appealable.
 SCE may be subject to penalties for noncompliance with customer notification and post event reporting requirements related to PSPS events initiated after 2020. In April 2023, the SED issued a Notice of Violation to SCE for noncompliance with customer notification and other CPUC requirements related to PSPS events in 2021. In November 2024, the CPUC approved an Administrative Consent Order and Agreement between SED and SCE to resolve all issues involving the 2021 PSPS events, resulting in financial penalties totaling $2.4 million. SCE has made and continues to make significant investments and progress in improving its PSPS protocols, including through increased automation of customer notifications.

 ENVIRONMENTAL CONSIDERATIONS

 Greenhouse Gas Regulation
 Edison International recognizes that its industry and the global economy are in the midst of a profound transformation toward a low-carbon future as a response to climate change. SCE plans to be a key enabler of the adoption of new energy technologies that benefit its customers. See "Management Overview—Electricity Industry Trends" in the MD&A.
 Approximately 73% of SCE's sources of utility-owned generation were carbon-free in 2024. SCE estimates that approximately 19% of power delivered to SCE's customers in 2024 came from SCE's own generating facilities, with approximately 9% nuclear, 4% large hydroelectric, less than 1% small hydroelectric, and less than 1% solar generation. Approximately 5% were natural gas sources. Since 2010, SCE has reported its annual GHG emissions from utility-owned generation each year to the U.S Environmental Protection Agency by March 31 of the following year. SCE's 2024 GHG emissions from utility-owned generation are estimated to be approximately 1,100,000 metric tons.
 California is committed to reducing its GHG emissions, improving local air quality and supporting continued economic growth. California's major initiatives for reducing GHG emissions include a law that targets the reduction of GHG emissions across the entire state economy to 40% below 1990 levels by 2030 and a California cap-and-trade program established by the California Air Resources Board ("CARB"). Other major policy measures include the Low Carbon Fuel Standard program established by CARB. In 2022, the California Climate Crisis Act declared the policy of the state to achieve net zero greenhouse gas emissions as soon as possible, but no later than 2045, to achieve and maintain net negative greenhouse gas emissions thereafter, and to ensure that by 2045, statewide anthropogenic greenhouse gas emissions are reduced to at least 85% below the 1990 levels. Edison International is committed to achieving net-zero GHG emissions by 2045, in alignment with economywide climate actions planned by California. This commitment covers the power SCE delivers to customers and Edison International's enterprise-wide operations.
 In the California cap-and-trade program, all covered GHG emitters, including SCE, are subject to an annually declining program "cap" on emissions designed to encourage entities to reduce emissions from their operations. Covered entities must remit a compliance instrument for each ton of carbon dioxide equivalent gas emitted and can do so buying state-issued emission allowances at auction or purchasing them in the secondary allowance market. From 2013 to 2020, GHG emitters could have met up to 8% of their cap-and-trade obligations by procuring GHG offset credits from verified offset programs, such as reforestation, that have recognized effects on reducing atmospheric GHGs. The offset usage limit has decreased to 4% for 2021 – 2025 emissions and will then increase to 6% for 2026 – 2030 emissions. Starting with 2021 emissions, no more than one-half of the quantitative offset usage limit may be sourced from projects that do not provide direct environmental benefits in California.
 California has adopted RPS targets that require California retail sellers of electricity to provide certain percentages of energy sales from renewable resources defined in the statute, including 33% of retail sales by December 2020; 44% of retail sales by December 2024, 52% of retail sales by December 2027, and 60% of retail sales by December 2030. Approximately 35% of SCE's supply portfolio in 2020 came from renewable sources eligible under California's RPS, of which 32% was delivered to customers and 3% was sold for resale. As such, SCE met California's 2020 RPS target. Approximately 38% of SCE's supply portfolio in 2024 came from renewable sources eligible under California's RPS, of which 34% was delivered to customers and 4% was sold for resale. With the use of excess procurement from prior years, as

 allowed under the RPS program, SCE expects to meet California's 44% RPS requirement for 2024. SCE's climate change objectives align with California's requirements. Separate from RPS targets, California requires the following percentages of retail sales of electricity to California end-use customers must be from carbon-free resources by the following deadlines: 90% by December 31, 2035, 95% by December 31, 2040, and 100% by December 31, 2045. California also requires each state agency to ensure that carbon-free resources supply 100% of electricity procured on its behalf by December 31, 2035. SCE plans to propose for CPUC approval new programs to help state agency customers meet their accelerated 100% clean power needs. SCE estimates that approximately 46% of SCE's customer deliveries in 2024 came from carbon-free resources.
 Additionally, the CPUC and the California Energy Commission adopted GHG emission performance standards that apply to California investor-owned and publicly owned utilities' long-term arrangements for the purchase of electricity. The standards prohibit these entities, including SCE, from owning or entering into long-term financial commitments with generators, such as coal plants, that emit more GHG than a combined-cycle natural gas turbine generator. California also supports climate action to meet the December 2015 Paris Agreement.
 Edison International supports these California environmental initiatives and has undertaken analysis which, consistent with third-party analysis, shows that electrification across multiple sectors, including transportation and industrial sectors, is among the most cost-effective ways to achieve California's requirements and goals. Edison International and SCE believe that these initiatives will lead to increased electrification across the economy and SCE is investing in grid technologies and charging infrastructure to support California's goals.

 Environmental Risks
 Climate change has, and continues to, impact California. According to the National Centers for Environmental Information, since 1980, California has faced 46 weather-related disasters costing over $1 billion each. In 2023, the Earth experienced its hottest year on record. This spike in temperature is making extreme weather events commonplace, with ripple effects that put people around the world in harm's way. Severe droughts and windstorms contributed to the devastating wildfires that swept through parts of California in recent years, demonstrating the serious threat that weather extremes caused by climate change pose to California's communities and the environment. See "Management Overview—Southern California Wildfires and Mudslides" in the MD&A and "Business—Southern California Wildfires."
 Severe weather events, including drought, increasingly severe windstorms and rising sea-levels, pose risks to SCE's infrastructure and SCE and Edison International are investing in building a more resilient grid to reduce climate- and weather-related vulnerabilities. See "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings" in the MD&A.
 In May 2022, SCE provided its climate adaptation vulnerability assessment ("CAVA") to the CPUC. The CAVA addresses the projected climate impacts of temperature, sea level, precipitation, wildfire, and cascading impacts (such as rain on snow or debris flow) on SCE in the 2030, 2050, and 2070 timeframes. SCE's CAVA will inform planning related to SCE assets, operations, and services, with the goal of maintaining a resilient electric grid in the face of climate change and will inform future investment in the grid.
 For more information on risks related to climate change, environmental regulation and SCE's business strategy, see "Risk Factors—Risks Relating to Southern California Edison Company—Operating Risks."

 UNRESOLVED STAFF COMMENTS
 None.

 CYBERSECURITY
 Overview
 Cybersecurity presents an ever-evolving challenge to the electric power industry and Edison International and SCE have identified cybersecurity as a key enterprise risk. SCE's operations require the continuous availability of critical information and operational technology systems, sensitive customer and employee data, and infrastructure information, all of which are targets for malicious actors. Cybersecurity attacks, which can arise from external actors, internal threats, or through SCE's supply chain, are continually becoming more frequent and more sophisticated. SCE's grid modernization efforts and the transition to a more connected grid, including incorporating communication and operating technologies aimed at enabling SCE to respond faster, operate its systems more efficiently and reliably, and incorporate DERs at a greater level, also increases SCE's vulnerability to cybersecurity attacks. To SCE's knowledge it has not experienced a material cybersecurity incident to date.
 SCE's increased reliance on technology necessarily increases cybersecurity risk. Cybersecurity incidents that may cause a major disruption of SCE's operations, and therefore may materially affect Edison International and SCE's financial

 condition, operations, and business reputation, include cyber attacks designed to compromise or exfiltrate data (e.g., ransomware attacks), damage or destroy systems, interrupt availability, conduct future malicious actions, and/or gain control of or otherwise interrupt the operation of SCE's electric grid. For additional information on risks from cybersecurity threats that may have a material effect on Edison International and SCE, see the "Risks Relating to Edison International and Southern California Edison Company—Cybersecurity and Physical Security Risks."
 Risk Management, Strategy and Oversight
 SCE assesses and monitors cybersecurity risks to current infrastructure, new projects, and third parties, including vendors. SCE maintains incident response plans, utilizes cybersecurity incident response exercises, performs targeted audits, leverages third party assessments and uses the National Institute of Standards and Technology (NIST) Cybersecurity Framework (CSF) as a guideline to identify, evaluate and manage material risks from cybersecurity threats. SCE also engages consultants, and coordinates with the Federal government and industry peers, to assist in identifying, evaluating and managing its cybersecurity risks, and uses contractual terms to establish cybersecurity requirements with certain third parties. Identified cybersecurity risks are documented and presented to management to review and advise on cybersecurity strategies and mitigation measures. Based on management reviews, cybersecurity strategies and remediation plans are developed or adjusted to address pertinent risks. Edison International and SCE leverage training, policies, technical and procedural controls, and mitigation plans to address risks from cybersecurity threats.
 Management has established a cybersecurity oversight group comprised of a multidisciplinary senior management team, including its Vice President of Enterprise Risk Management, to monitor and provide strategic direction for the prevention, detection, mitigation, and remediation of risks from cybersecurity threats. A Boards of Directors' liaison regularly attends meetings of the cybersecurity oversight group and provides reports to the Safety and Operations Committees of the Boards of Directors. Other members of the Boards of Directors are invited to attend meetings and typically attend at least one meeting annually.
 The Edison International and SCE Audit and Finance Committees of the Boards of Directors oversee enterprise risk management, including risks from cybersecurity threats. Annually, Edison International and SCE's enterprise risk management team conducts a review of enterprise risks, including risks from cybersecurity threats, and presents the results of its review to management and the Audit and Finance Committees. In addition, the Boards of Directors have assigned primary responsibility for cybersecurity operations oversight to the Edison International and SCE Safety and Operations Committees, which receive regular cybersecurity updates from SCE's Chief Security Officer on specific topics, including the dynamic cybersecurity landscape and defense and risk mitigation strategies. To inform its oversight over cybersecurity threats, SCE's Chief Security Officer also presents to the full Boards of Directors annually. The Boards of Directors also receive a periodic cybersecurity report from an external SCE consultant that includes an assessment of SCE's cybersecurity program and organization.
 SCE's Chief Security Officer has primary responsibility for assessing and managing risks from cybersecurity threats, and serves as Edison International and SCE's chief information security officer. SCE's Chief Security Officer has extensive experience in the cybersecurity industry, including previous experience in cybersecurity roles at Southern Company, the MITRE Corporation, the National Institute of Standards and Technology (NIST), and the Federal Bureau of Investigation (FBI). SCE's Chief Security Officer earned a bachelor's degree in computer information systems from Clemson University and is a Certified Information Systems Security Professional (CISSP).
 For additional information on the Edison International Board of Directors cybersecurity related experience and oversight of cybersecurity risk management, see Edison International's Proxy Statement under the headings "Director Skills Matrix" and "Board Oversight of Strategy, Risk and ESG."

 PROPERTIES
 As a holding company, Edison International does not directly own any significant properties other than the stock of its subsidiaries. The principal properties of SCE are described above under "Business—SCE—Properties."

 LEGAL PROCEEDINGS

 The lawsuits related to the 2017/2018 Wildfire/Mudslide Events naming SCE as a defendant have been filed by three categories of plaintiffs: individual plaintiffs, subrogation plaintiffs and public entity plaintiffs. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 20, 2025, in addition to the outstanding claims of approximately 290 claims of approximately 15,000 initial individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding. SCE has settled all fire suppression claims and subrogation plaintiffs' related to the 2017/2018 Wildfire/Mudslide Events.

 The litigation could take a number of years to be completely resolved because of the complexity of the matters and number of plaintiffs. The statutes of limitations for individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events have expired. As of February 20, 2025, SCE has received demands for approximately 94% and 100% of outstanding individual plaintiff claims in the TKM litigation and Woolsey Fire litigation, respectively.
 As of February 20, 2025, SCE was aware of approximately 30 pending unsettled lawsuits representing approximately 70 individual plaintiffs related to the Thomas and Koenigstein Fires and the Montecito Mudslides naming SCE as a defendant. Approximately 10 of the approximately 30 lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. One of the lawsuits was filed as a purported class action. The lawsuits, which have been filed in the superior courts of Ventura, Santa Barbara and Los Angeles Counties allege, among other things, negligence, inverse condemnation, trespass, private nuisance, and violations of the public utilities and health and safety codes. SCE and certain of the individual plaintiffs in the Thomas and Koenigstein Fire litigation have been pursuing settlements of claims under a mediation program adopted to promote an efficient and orderly settlement process. As of February 20, 2025, damages only trials have been set for June and August 2025 for two individual plaintiff households in the TKM litigation.
 As of February 20, 2025, SCE was aware of approximately 70 currently pending unsettled lawsuits representing approximately 220 individual plaintiffs related to the Woolsey Fire naming SCE as a defendant. Approximately 60 of the 70 lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. The lawsuits, which have been filed in the superior courts of Ventura and Los Angeles Counties allege, among other things, negligence, inverse condemnation, personal injury, wrongful death, trespass, private nuisance, and violations of the public utilities and health and safety codes. SCE and certain of the individual plaintiffs in the Woolsey Fire litigation have been pursuing settlements of claims under a mediation program adopted to promote an efficient and orderly settlement process. As of February 20, 2025, a damages only trial has been set for May 2025 for one individual plaintiff household in the Woolsey Fire litigation.
 The Thomas and Koenigstein Fires and Montecito Mudslides lawsuits are being coordinated in the Los Angeles Superior Court. The Woolsey Fire lawsuits have also been coordinated in the Los Angeles Superior Court.
 Eaton Fire

 In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage and service outages for SCE customers. One of the largest of these wildfires, the Eaton Fire, ignited in SCE's service area in Los Angeles County and spread under conditions of an extreme Santa Ana windstorm.
 As of February 20, 2025, SCE was aware of approximately 90 currently pending unsettled lawsuits representing approximately 1,400 individual plaintiffs related to the Eaton Fire naming SCE and Edison International as defendants.

 For information on the 2017/2018 Wildfire/Mudslide Events and the Eaton Fire, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" in this report.

 Environmental Proceedings
 Each of Edison International and SCE have elected to disclose environmental proceedings described in Item 103(c)(3)(iii) of Regulation SK unless it reasonably believes that such proceeding will result in no monetary sanctions, or in monetary sanctions, exclusive of interest and costs, of less than $1.0 million.
 Mission Canyon
 SCE performed 1.6 miles of access road grading and vegetation clearing in the Mission Canyon area of Santa Barbara County in December 2019, resulting in debris moving downslope into a creek bed and other impacts in the area (the "Mission Canyon Incident"). Several state and federal environmental agencies and the County and City of Santa Barbara have investigated the unpermitted grading and discharges to the creek, and SCE has received Notices of Violation from the Army Corps of Engineers, the County of Santa Barbara, the California Department of Fish & Wildlife and the Regional Water Quality Control Board. In December 2020, SCE and the Santa Barbara County District Attorney entered into a settlement regarding alleged criminal and civil violations related to the Mission Canyon Incident. Under the settlement, SCE pled no contest to a single misdemeanor charge for violation of the California Water Code and agreed to pay a $10,000 fine. SCE also agreed to pay a civil penalty of $3.5 million and is subject to an injunction compelling it to complete planned remediation work related to the Mission Canyon Incident and not commit similar violations for five years. It is presently unknown whether any regulatory agencies will impose additional fines or penalties on SCE with respect to the Mission Canyon Incident and, if so, in what amounts. SCE does not expect fines or penalties that are imposed in connection with the Mission Canyon Incident to be material.

 MINE SAFETY DISCLOSURE
 Not applicable.

 CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL

 INFORMATION ABOUT OUR EXECUTIVE OFFICERS

 Executive Officer
 Age at
 February 20, 2025

 Company Position

 Pedro J. Pizarro
 President and Chief Executive Officer

 Maria Rigatti
 Executive Vice President and Chief Financial Officer

 Adam S. Umanoff
 Executive Vice President, General Counsel and Corporate Secretary

 Caroline Choi
 Senior Vice President, Corporate Affairs and Public Policy

 Natalie K. Schilling
 Senior Vice President and Chief Human Resources Officer

 Erica S. Bowman

 Vice President, Strategy, Planning and Performance

 Steven D. Powell
 President and Chief Executive Officer, SCE

 Jill C. Anderson
 Executive Vice President and Chief Operating Officer, SCE

 J. Andrew Murphy
 President and Chief Executive Officer, Trio

 As set forth in Article IV of Edison International's Bylaws, the elected officers of Edison International are chosen annually by, and serve at the pleasure of, the Edison International Board of Directors and hold their respective offices until their resignation, removal, other disqualification from service, or until their respective successors are elected. All of the officers of Edison International have been actively engaged in the business of Edison International and its subsidiaries for more than five years, except for Ms. Schilling, and have served in their present positions for the periods stated below. Additionally, those officers who have had other or additional principal positions in the past five years had the following business experience during that period:

 Executive Officers
 Company Position
 Effective Dates

 Pedro J. Pizarro
 President and Chief Executive Officer, Edison International

 October 2016 to present

 Maria Rigatti
 Executive Vice President and Chief Financial Officer, Edison International
 October 2016 to present

 Adam S. Umanoff
 Corporate Secretary, Edison International and SCE
 Executive Vice President and General Counsel, Edison International

 December 2023 to present
 January 2015 to present

 Caroline Choi
 Senior Vice President, Corporate Affairs and Public Policy, Edison International and SCE
 Senior Vice President, Corporate Affairs, Edison International and SCE

 February 2024 to present

 February 2019 to February 2024

 Natalie K. Schilling
 Senior Vice President and Chief Human Resources Officer, Edison International and SCE
 Vice President, Human Resources, Edison International and SCE
 Chief Human Resources Officer, Aerojet Rocketdyne Holdings, Inc.1

 March 2022 to present

 April 2020 to February 2022
 April 2018 to January 2020

 Erica S. Bowman

 Vice President, Strategy, Planning and Performance, Edison International and SCE
 Managing Director, Regulatory Policy and Strategic Analysis, SCE
 Director, CEO's Office, Edison International
 Director, Resource & Environmental Policy Strategy, SCE

 February 2024 to Present
 August 2022 to February 2024
 November 2020 to July 2022
 July 2018 to November 2020

 Steven D. Powell
 President and Chief Executive Officer, SCE
 Executive Vice President, Operations, SCE

 December 2021 to present
 September 2019 to December 2021

 Jill C. Anderson
 Executive Vice President and Chief Operating Officer, SCE
 Senior Vice President, Customer Service, SCE
 Senior Vice President, Strategic Planning and Power Supply, SCE

 December 2021 to present
 March 2020 to December 2021
 September 2019 to March 2020

 J. Andrew Murphy
 President and Chief Executive Officer, Trio
 Senior Vice President, Strategy and Corporate Development, Edison International

 July 2023 to present
September 2015 to July 2023

 1Aerojet Rocketdyne Holdings, Inc. was an aerospace and defense firm acquired by L3Harris Technologies, Inc. on July 28, 2023, and is not a parent, affiliate or subsidiary of Edison International

 DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
 Information concerning executive officers of Edison International is set forth above under "Information about our Executive Officers." Other information responding to this section will appear in the Edison International Proxy
 Statement under the headings "Our Director Nominees," "Director Skills Matrix," "Director Biographies," and is incorporated herein by this reference.
 Code of Ethics
 The Edison International Employee Code of Conduct is applicable to all officers and employees of Edison International and its subsidiaries. The Code is available on Edison International's Internet website at www.edisoninvestor.com at "Corporate Governance." Any amendments or waivers of Code provisions for the Company's principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions, will be posted on Edison International's Internet website at www.edisoninvestor.com.
 Insider Trading Policy and Procedures
 Edison International has adopted an insider trading policy that governs the purchase, sale and other dispositions of all securities of Edison International and its subsidiaries by Edison International and SCE directors, officers, employees and certain third parties. The adopted policy is designed to promote compliance with insider trading laws, rules and regulations, and any listing standards applicable to Edison International and SCE.

 The insider trading policy also restricts trading and other transactions for a limited group of covered persons who include Edison International and SCE directors, executive officers, and certain employees whose duties involve access to material non-public information, to defined window periods that follow the Edison International and SCE quarterly earnings releases. A copy of Edison International's insider trading policy is filed with this Annual Report on Form 10-K as Exhibit 19. In addition, with regard to the Edison International trading in its own securities, it is Edison International's policy to comply with the federal securities laws and the applicable exchange listing requirements.

 EXECUTIVE COMPENSATION
 Information responding to this section will appear in the Edison International Proxy Statement under the headings "Compensation Discussion and Analysis," "Executive Compensation" (other than "—Pay Versus Performance") and "Director Compensation" and is incorporated herein by this reference.

 SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
 Information responding to this section will appear in the Edison International Proxy Statement under the heading "Stock Ownership" and is incorporated herein by this reference.
 Equity Compensation Plan Information
 All of Edison International's equity compensation plans that were in effect as of December 31, 2024 have been approved by security holders. The following table sets forth, for each of Edison International's equity compensation plans, the number of shares of Edison International Common Stock subject to outstanding options, warrants and rights to acquire such stock, the weighted average exercise price of those outstanding options, warrants and rights, and the number of shares remaining available for future award grants as of December 31, 2024.

 Plan Category
 Number of securities to
be issued upon exercise
of outstanding options,
 warrants and rights
(a)
 Weighted average
exercise price of
outstanding options,
warrants and rights
(b)
 Number of securities remaining for
future issuance under equity
compensation plans (excluding
securities reflected in column
(a)(c)

 Equity compensation plans approved by security holders
 10,239,8741

 $64.33
 12,595,7822

 1This amount includes 8,643,575 shares covered by outstanding stock options, 876,448 shares covered by outstanding restricted stock unit awards, 201,331 shares covered by outstanding deferred stock unit awards, and 518,520 shares covered by outstanding performance share awards (calculated at 100% of the target number of shares subject to each performance share award; the actual payout for each award will be zero to twice the target number of shares for the award, depending on performance), with the outstanding shares covered by outstanding restricted stock unit, deferred stock unit, and performance share awards including the crediting of dividend equivalents through December 31, 2024. The weighted average exercise price of awards outstanding under equity compensation plans approved by security holders reflected in column (b) above is calculated based on the outstanding stock options under these plans as the other forms of awards outstanding have no exercise price. Awards payable solely in cash are not reflected in this table.
 2This amount is the aggregate number of shares available for new awards under the Edison International 2007 Performance Incentive Plan and the Edison International Employee Stock Purchase Plan as of December 31, 2024, consisting of 9,723,890 shares and 2,871,892 shares, respectively. The maximum number of shares of Edison International Common Stock authorized for issuances or transfers pursuant to awards under the Edison International 2007 Performance Incentive Plan is 71,031,524. Shares available under the Edison International 2007 Performance Incentive Plan may generally, subject to certain limits set forth in the plan, be used for any type of award authorized under that plan, including stock options, restricted stock, performance shares, restricted or deferred units, and stock bonuses. The maximum number of shares of Edison International Common Stock authorized under the Edison International Employee Stock Purchase Plan is 3,000,000.

 CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
 Information responding to this section will appear in the Edison International Proxy Statement under the headings "Governance Structure and Processes—Certain Relationships and Related Party Transactions," and "Governance Structure and Processes—Director Independence," and is incorporated herein by this reference.

 PRINCIPAL ACCOUNTANT FEES AND SERVICES
 PricewaterhouseCoopers LLP ("PwC") served as Edison International's and SCE's principal accountant in 2024. Information responding to this section for Edison International will appear in the Edison International Proxy Statement under the heading "Independent Auditor Fees," and is incorporated herein by this reference.

 The following table sets forth the aggregate fees billed by PwC to SCE for the fiscal years ended December 31, 2024 and 2023:

 SCE ($000)

 Type of Fee
 2024
 2023

 Audit Fees1

 $
 6,026
 $
 5,975

 Audit-Related Fees2

 —

 Tax Fees3

 All Other Fees4

 Total
 $
 6,920
 $
 6,436

 1Represent fees for professional services provided in connection with the audit of SCE's annual financial statements and reviews of SCE's quarterly financial statements and for services regularly provided by PwC in connection with regulatory filings or engagements.
 2These represent fees for assurance and related services related to the performance of the audit or review of the financial statements and not reported under "Audit Fees" above.
 3Represent fees for tax-related compliance and other tax-related services to support compliance with federal and state tax reporting and payment requirements, including tax return review and review of tax laws, regulations or case precedent.
 4Represent fees for miscellaneous services. "All Other Fees" included fees for attestation services related to a CPUC required report on wildfire memorandum accounts and to securitizations for the year ended December 31, 2024. "All Other Fees" included fees for attestation services related to securitizations for the year ended December 31, 2023.
 The SCE Audit and Finance Committee annually approves all proposed audit fees in executive session without PwC present, considering several factors, including a breakdown of the services to be provided, proposed staffing and hourly rates, and changes in SCE and industry from the prior year. The audit fees are the culmination of a process which included a comparison of the prior year's proposed fees to actual fees incurred and fee proposals for known and anticipated 2024 services in the audit, audit-related, tax and other categories. The committee's deliberations consider balancing the design of an audit scope that will achieve a high-quality audit with driving efficiencies from both SCE and PwC while compensating PwC fairly.
 The SCE Audit and Finance Committee is required to pre-approve all audit and permitted non-audit services performed by PwC to ensure these services will not impair the firm's independence. The SCE Audit and Finance Committee has delegated to the Committee Chair the authority to pre-approve services between committee meetings, provided that any pre-approval decisions are presented to the committee at its next meeting. PwC must assure that all audit and non-audit services provided to SCE have been approved by the SCE Audit and Finance Committee.
 During the fiscal year ended December 31, 2024, all services performed by PwC were pre-approved by the SCE Audit and Finance Committee, irrespective of whether the services required pre-approval under the Securities Exchange Act of 1934.

 MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

 Edison International Common Stock is traded on the New York Stock Exchange under the symbol "EIX."
 There are restrictions on the ability of SCE to transfer funds to Edison International that materially limit the ability of Edison International to pay cash dividends. Such restrictions are discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." The number of common stockholders of record of Edison International was 23,501 on February 20, 2025. In addition, Edison International cannot pay dividends if it does not meet California law requirements on retained earnings and solvency.

 As a result of the formation of a holding company described under the heading "Business" above, all of the issued and outstanding common stock of SCE is owned by Edison International and there is no market for such stock. There are restrictions on SCE's ability to pay dividends to Edison International and to its preference shareholders. Such restrictions are discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."

 Purchases of Equity Securities by Edison International and Affiliated Purchasers
 The following table contains information about all purchases of Edison International's common stock made by or on behalf of Edison International in the fourth quarter of 2024. For further information about Edison International's common stock repurchase programs, see "Notes to Consolidated Financial Statements—Note 14. Equity."

 Period
 (a) Total Number of Shares (or Units Purchased)

 (b) Average Price Paid per Share (or Unit)

 (c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs1

 (d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs

 October 1, 2024 to October 31, 2024

 —
 —
 —
 —

 November 1, 2024 to November 30, 2024

 2,412,203
 $
 82.91
 2,412,203
 —

 December 1, 2024 to December 31, 2024

 —
 —
 —
 —

 Total
 2,412,203
 2,412,203

 1Purchases were made pursuant to Edison International's common stock repurchase program announced on July 25, 2024.

 Comparison of Five-Year Cumulative Total Return

 At December 31,

 2019
 2020

 2021

 2022

 2023

 2024

 $
 $
 $
 $
 $
 $

 S & P 500 Index
 $
 $
 $
 $
 $
 $

 PHLX Utility Sector Index

 $
 $
 $
 $
 $
 $

 Note: Assumes $100 invested on December 31, 2019, in stock or index including reinvestment of dividends. Performance of the PHLX Utility Sector Index is regularly reviewed by management and the Board of Directors in understanding Edison International's relative performance and is used in conjunction with elements of Edison International's compensation program.

 OTHER INFORMATION

 Insider Trading Arrangements
 During the quarter ended December 31, 2024, no director or Section 16 officer adopted or terminated any Rule 10b5-1 trading arrangements or non-Rule 10b5-1 trading arrangements (in each case, as defined in Item 408(a) of Regulation S-K).
 PART II, ITEM 6. Reserved.
 This item no longer requires disclosure.

 FORM 10-K SUMMARY
 None.

 DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
 Not applicable.

 EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
 (a) (1) Financial Statements
 See Consolidated Financial Statements listed in the Table of Contents of this report.
 (a) (2) Report of Independent Registered Public Accounting Firm and Schedules Supplementing Financial Statements
 The following documents may be found in this report at the indicated page numbers under the headings "Financial Statements and Supplementary Data—Reports of Independent Registered Accounting Firm" and "Exhibits and Financial Statement Schedules—Schedules Supplementing Financial Statements" in the Table of Contents of this report.
 Report of Independent Registered Public Accounting Firm - Edison International
 Schedule I – Condensed Financial Information of Edison International Parent
 Schedules II through V, inclusive, for Edison International are omitted as not required or not applicable.
 The following documents may be found in this report at the indicated page numbers under the headings "Financial Statements and Supplementary Data—Reports of Independent Registered Accounting Firm" and "Exhibits and Financial Statement Schedules—Schedules Supplementing Financial Statements" in the Table of Contents of this report.
 Report of Independent Registered Public Accounting Firm - SCE
 Schedules I through V, inclusive, for SCE are omitted as not required or not applicable.
 (a) (3) Exhibits

 EXHIBIT INDEX

 3.1
 Certificate of Restated Articles of Incorporation of Edison International, effective December 19, 2006, together with all Certificates of Determination of Preference of Preferred Stock issued since December 19, 2006 (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*

 3.2
 Bylaws of Edison International, as amended effective, December 8, 2022 (File No. 1-9936, filed as Exhibit No. 3.1 to Edison International's Form 8-K dated December 8, 2022 and filed December 9, 2022)*

 3.3
 Amended and Restated Articles of SCE, effective August 28, 2023 (Filed No. 1-2313 filed as Exhibit 3.1 to SCE's Form 8-K dated September 19, 2023 and filed September 21, 2023)*

 3.4
 Bylaws of Southern California Edison Company, as amended effective December 8, 2022 (File No. 1-2313, filed as Exhibit No. 3.2 to SCE's Form 8-K dated December 8, 2022 and filed December 9, 2022)*

 4.1
 Edison International - Description of Registered Securities (File No. 1-9936, filed as Exhibit 4.1 to Edison International's Form 10-K for the year ended December 31, 2019)*

 4.2
 Senior Indenture, dated September 10, 2010 (File No. 1-9936, filed as Exhibit 4.1 to Edison International's Form 10-Q for the quarter ended September 30, 2010)*

 4.3
 Junior Subordinated Indenture, dated as of March 1, 2023, between Edison International and The Bank of New York Mellon Company, as Trustee

 4.4
 Form of Certificate representing Series A Preferred Stock (included as Exhibit A to Certificate of Determination of the 5.375% Fixed Rate Reset Cumulative Perpetual Preferred Stock Series A) (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*

 4.5
 Form of Certificate representing Series B Preferred Stock (included as Exhibit A to Certificate of Determination of the 5.00% Fixed Rate Reset Cumulative Perpetual Preferred Stock Series B) (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*

 4.6
 Southern California Edison Company First Mortgage Bond Trust Indenture, dated as of October 1, 1923 (File No. 1-2313, filed as Exhibit 4.2 to SCE's Form 10-K for the year ended December 31, 2010)*

 4.7
 Southern California Edison Company Indenture, dated as of January 15, 1993 (File No. 1-2313, filed as Exhibit 4.3 to SCE's Form 10-K for the year ended December 31, 2017)*

 4.8
 Certificate of Determination of Preferences of the Company's Series M Preference Stock (File No. 1-2313, filed as Exhibit 4.1 to SCE's Form 8-K dated November 16, 2023 and filed on November 22, 2023)*

 4.9
 Certificate of Determination of Preferences of the Company's Series N Preference Stock (File No. 1-2313, filed as Exhibit 4.1 to SCE's Form 8-K dated and filed on May 7, 2024)*

 Edison International and Southern California Edison Company

 10.1**
 Edison International 2008 Director Deferred Compensation Plan, as amended and restated effective January 1, 2021 (File No. 1-9936, filed as Exhibit No. 10.2 to Edison International's Form 10-Q for the quarter ended September 30, 2020)*

 10.2**
 Edison International Executive Deferred Compensation Plan, as amended and restated effective June 19, 2014 (as amended) (File No. 1-9936, filed as Exhibit No. 10.7 to Edison International's Form 10-Q for the quarter ended March 31, 2018)*

 10.3**
 Edison International 2008 Executive Deferred Compensation Plan, as amended and restated effective January 1, 202 5

 10.4**
 Southern California Edison Company Executive Retirement Plan, as amended effective June 19, 2014 (File No. 1-9936, filed as Exhibit 10.7 to Edison International and SCE's Form 10-Q for the quarter ended June 30, 2014)*

 10.4.1**
 Edison International 2008 Executive Retirement Plan, as amended and restated effective January 1, 202 5

 10.5**
 Edison International Executive Incentive Compensation Plan, as amended and restated effective January 1, 202 5

 10.6**
 Edison International 2008 Executive Disability Plan, as amended and restated effective January 1, 2025

 10.7**
 Edison International 2007 Performance Incentive Plan as amended and restated effective May 2, 2016 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated April 28, 2016 and filed April 29, 2016)*

 10.7.1**

 Edison International 2015 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.2 to Edison International's Form 10-Q for the quarter ended March 31, 2015)*

 10.7.2**

 Edison International 2016 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended March 31, 2016)*

 10.7.3**

 Edison International 2017 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.2 to Edison International's Form 10-Q for the quarter ended March 31, 2017)*

 10.7.4**

 Edison International 2018 Long-Term Incentives Terms and Conditions (File. No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended March 31, 2018)*

 10.7.5**

 Edison International 2019 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended March 31, 2019)*

 10.7.6**

 Edison International 2020 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended March 31, 2020)*

 10.7.7**

 Edison International 2021 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2021)*

 10.7.8**

 Edison International 2022 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2022)*

 10.7.9**

 Edison International 2023 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2023)*

 10.7.10**

 Edison International 2024 Long-Term Incentives Terms and Conditions (File No 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2024)*

 10.8**
 Edison International 2008 Executive Severance Plan, as amended and restated effective January 1, 2025

 10.9**
 Edison International and Southern California Edison Company Director Compensation Schedule, as adopted December 8, 2023 (File No. 1-9936, filed as Exhibit 10.9 to Edison International's Form10-K for the year ended December 31, 2023)*

 10.10**
 Edison International Director Matching Gifts Program, as revised effective January 1, 2019 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended September 30, 2019)*

 10.11
 Amended and Restated Agreement for the Allocation of Income Tax Liabilities and Benefits among Edison International, Southern California Edison Company and The Mission Group dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*

 10.12
 Amended and Restated Tax-Allocation Agreement among The Mission Group and its first-tier subsidiaries dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3.1 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*

 10.12.1
 Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.11 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*

 10.12.2
 Modification No. 1 to the Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.1 to Edison Mission Energy's Form 8-K dated November 15, 2012 and filed November 21, 2012)*

 10.12.3
 Amended and Restated Administrative Agreement Re Tax Allocation Payments, dated February 13, 2012, among Edison International and subsidiary parties. (File No. 333-68630, filed as Exhibit 10.12 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*

 10.13**
 Form of Indemnity Agreement between Edison International and its Directors and any officer, employee or other agent designated by the Board of Directors (File No. 1-9936, filed as Exhibit 10.5 to Edison International's Form 10-Q for the quarter ended June 30, 2005)*

 10.14
 Second Amended and Restated Credit Agreement dated as of May 17, 2018 among Edison International, the several banks and other financial institutions from time to time parties thereto, the several agents parties thereto and JPMorgan Chase Bank, N.A., as administrative agent for the lenders. (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated and filed May 18, 2018)*

 10.15
 First Amendment, dated as of April 30, 2021, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase bank, N.A., as administrative agent. (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated April 30, 2021 and filed May 6, 2021)*

 10.16
 Second Amendment, dated as of May 4, 2022, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated and filed May 4, 2022)*

 10.17
 Third Amendment, dated as of May 3, 2023, to the Second Amended and Restated Credit Agreement dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021 and the Second Amendment, dated as of May 4, 2022, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended June 30, 2023)*

 10.18
 Second Amended and Restated Credit Agreement dated as of May 17, 2018 among SCE, the several banks and other financial institutions from time to time parties thereto, the several agents parties thereto and JPMorgan Chase Bank, N.A., as administrative agent for the lenders. (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated and filed May 18, 2018)*

 10.19
 First Amendment, dated as of April 30, 2021, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, by and among Southern California Edison Company, the several banks and other financial institutions party thereto and JPMorgan Chase bank, N.A., as administrative agent. (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated April 30, 2021 and filed May 6, 2021)*

 10.20
 Commitment Increase Supplement, by and among Southern California Edison Company and the lenders named therein, and accepted by JPMorgan Chase Bank, N.A., as administrative agent and the issuing lenders named therein. (File No. 1-2313, filed as Exhibit 10.3 to SCE's Form 8-K dated April 30, 2021 and filed May 6, 2021)*

 10.21
 Second Amendment, dated as of May 4, 2022, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021, as supplemented by the Commitment Increase Supplement, dated as of April 30, 2021, by and among Southern California Edison Company, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated and filed May 4, 2022)*

 10.22
 Third Amendment, dated as of May 3, 2023, to the Second Amended and Restated Credit Agreement dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021 and the Second Amendment, dated as of May 4, 2022, by and among Southern California Edison, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 10-Q for the quarter ended June 30, 2023)*

 19.1
 Edison International Insider Trading Policy

 21.1
 Subsidiaries of the Registrants

 23.1
 Consent of Independent Registered Public Accounting Firm (Edison International)

 23.2
 Consent of Independent Registered Public Accounting Firm (Southern California Edison Company)

 24.1
 Powers of Attorney of Edison International and Southern California Edison Company

 24.2
 Certified copies of Resolutions of Boards of Edison International and Southern California Edison Company Directors Authorizing Execution of SEC Reports

 31.1
 Certifications of the Chief Executive Officer and Chief Financial Officer of Edison International pursuant to Section 302 of the Sarbanes-Oxley Act

 31.2
 Certifications of the Chief Executive Officer and Chief Financial Officer of Southern California Edison Company pursuant to Section 302 of the Sarbanes-Oxley Act

 32.1
 Certifications of the Chief Executive Officer and the Chief Financial Officer of Edison International required by Section 906 of the Sarbanes-Oxley Act

 32.2
 Certifications of the Chief Executive Officer and the Chief Financial Officer of Southern California Edison Company required by Section 906 of the Sarbanes-Oxley Act

 97.1
 Edison International and Southern California Edison Company Incentive Compensation Recoupment Policy For Accounting Restatements, as amended effective October 2, 2023 (File No. 1-9936, filed as Exhibit 97.1 to Edison International's Form10-K for the year ended December 31, 2023)*

 101.1

 101.2

 *Incorporated by reference pursuant to Rule 12b-32.
 **Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3).
 Edison International and SCE will furnish a copy of any exhibit listed in the accompanying Exhibit Index upon written request and upon payment to Edison International or SCE of their reasonable expenses of furnishing such exhibit, which shall be limited to photocopying charges and, if mailed to the requesting party, the cost of first-class postage.

 SCHEDULES SUPPLEMENTING FINANCIAL STATEMENTS
 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
 CONDENSED BALANCE SHEETS

 2024
 2023

 Assets:

 $
 $

 Other current assets

 Total current assets

 Investments in subsidiaries
 20,630
 20,026

 Other long-term assets

 $
 22,067
 $
 21,226

 Liabilities and equity:

 Short-term debt
 $
 $

 Other current liabilities

 Total current liabilities
 1,884
 1,344

 Long-term debt
 4,268
 4,019

 Other long-term liabilities

 Total equity
 15,565
 15,501

 Total liabilities and equity
 $
 22,067
 $
 21,226

 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
 CONDENSED STATEMENTS OF INCOME
 For the Years Ended December 31, 2024, 2023 and 2022

 2024
 2023
 2022

 Interest income
 $
 $
 $

 Operating, interest and other expenses

 Loss before equity in earnings of subsidiaries
 ( 339)
 ( 297)
 ( 206)

 Equity in earnings of subsidiaries
 1,610
 1,498

 Income before income taxes
 1,271
 1,201

 Income tax benefit
 ( 100)
 ( 83)
 ( 56)

 1,371
 1,284

 Preferred stock dividend requirements of Edison International

 Net income available to Edison International common shareholders
 $
 1,284
 $
 1,197
 $

 CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
 For the Years Ended December 31, 2024, 2023 and 2022

 2024
 2023
 2022

 $
 1,371
 $
 1,284
 $

 Other comprehensive income, net of tax

 Comprehensive income
 $
 1,380
 $
 1,286
 $

 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
 CONDENSED STATEMENTS OF CASH FLOWS
 For the Years Ended December 31, 2024, 2023 and 2022

 2024
 2023
 2022

 $
 1,097
 $
 1,148
 $
 1,133

 Cash flows from financing activities:

 Long-term debt issued
 1,049
 1,549

 Long-term debt issuance costs
 ( 7)
 ( 16)
 ( 6)

 Long-term debt repaid
 ( 500)
 ( 400)
 ( 700)

 Short-term debt issued
 —
 1,000

 Short-term debt repaid
 ( 15)
 ( 1,356)
 —

 Common stock issued

 Common stock repurchased
 —
 —

 Preferred stock repurchased
 ( 28)
 ( 289)
 —

 Payable due to affiliates
 —
 ( 3)
 ( 14)

 Commercial paper borrowing (repayments), net

 Payments for stock-based compensation
 ( 24)
 ( 5)
 ( 8)

 Receipts for stock-based compensation

 Common stock dividends paid
 ( 1,198)
 ( 1,112)
 ( 1,050)

 Preferred stock dividends paid
 ( 88)
 ( 99)

 Net cash (used in) provided by financing activities
 ( 579)
 ( 1,140)

 Cash flows from investing activities:

 Capital contributions to affiliate
 ( 516)
 ( 15)
 ( 1,426)

 Dividends from affiliate

 Net cash used in investing activities:
 ( 515)
 ( 11)
 ( 1,423)

 Net increase (decrease) in cash and cash equivalents
 ( 3)
 ( 48)

 Cash and cash equivalents, beginning of year

 Cash and cash equivalents, end of year
 $
 $
 $

 Note 1. Basis of Presentation
 The accompanying condensed financial statements of Edison International Parent should be read in conjunction with the consolidated financial statements and notes thereto of Edison International and subsidiaries ("Registrant") included in this Form 10-K. Edison International Parent's significant accounting policies are consistent with those of the Registrant, SCE and other wholly owned and controlled subsidiaries.
 Dividends Received
 Edison International Parent received cash dividends from SCE of $ 1.4 billion, $ 1.4 billion and $ 1.3 billion in 2024, 2023 and 2022, respectively.
 Dividend Restrictions
 For information on Edison International Parent dividend restrictions, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends" and "—Edison International Dividends."
 Note 2. Debt and Equity Financing
 Long-Term Debt
 The following table summarizes Edison International Parent's long-term debt at December 31, 2024:

 4.95 % Senior Note due 2025

 $

 4.70 % Senior Note due 2025

 5.75 % Senior Note due 2027

 4.125 % Senior Note due 2028

 5.25 % Senior Note due 2028

 6.95 % Senior Note due 2029

 5.45 % Senior Note due 2029

 5.25 % Senior Note due 2032

 8.125 % Junior Subordinated Note due 2053

 7.875 % Junior Subordinated Note due 2054

 For information on Edison International Parent's material provisions on long-term debt and credit facility, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Liens and Security Interests" and "—Credit Agreements and Short-Term Debt."
 Common and Preferred Stock
 For information on Edison International Parent common stock and preferred stock, see "Notes to Consolidated Financial Statements—Note 14. Equity."
 Note 3. Related-Party Transactions
 Edison International's Parent expense from services provided by SCE was $ 2 million in 2024, $ 2 million in 2023 and $ 2 million in 2022. Edison International Parent's interest expense from loans due to affiliates was $ 2 million in 2024, $ 2 million in 2023 and $ 3 million in 2022. Edison International Parent had current related-party receivables of $ 571 million and $ 400 million and current related-party payables of $ 186 million and $ 185 million at December 31, 2024 and 2023, respectively. Edison International Parent had long-term related-party payables of $ 98 million and $ 112 million at December 31, 2024 and 2023, respectively. For a discussion of Edison International Parent's contribution to Edison International Foundation for the year ended December 31, 2024, see "Notes to Consolidated Financial Statements—Note 18. Related Party Transactions".
 Note 4. Contingencies
 For a discussion of material contingencies see "Notes to Consolidated Financial Statements—Note 8. Income Taxes" and "—Note 12. Commitments and Contingencies."

 SIGNATURES
 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.

 SOUTHERN CALIFORNIA EDISON COMPANY

 By:
 By:

 (Duly Authorized Officer and
 Principal Accounting Officer)

 (Duly Authorized Officer and
 Principal Accounting Officer)

 Date:
 Date:

 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrants and in the capacities and on the date indicated.

 Signature
 Title

 A. Principal Executive Officers

 Pedro J. Pizarro*
 President, Chief Executive Officer and Director
 (Edison International)

 Steven D. Powell*
 President and Chief Executive Officer and Director (Southern California Edison Company)

 B. Principal Financial Officers

 Maria Rigatti*
 Executive Vice President and Chief Financial Officer
 (Edison International)

 Aaron D. Moss*
 Senior Vice President and Chief Financial Officer
 (Southern California Edison Company)

 C. Principal Accounting Officers

 (Edison International)

 (Southern California Edison Company)

 D. Directors (Edison International and Southern California Edison Company, unless otherwise noted)

 Jeanne Beliveau-Dunn*

 Michael C. Camu ez*

 Vanessa C.L. Chang*

 James T. Morris*

 Timothy T. O'Toole*

 Pedro J. Pizarro*

 Steven D. Powell (SCE only)*

 Marcy L. Reed*

 Carey A. Smith*

 Linda G. Stuntz*

 Peter J. Taylor*
 Chair of the Edison International Board and Director

 Keith Trent*

 *By:
 *By:

 (Attorney-in-fact for EIX Directors and Officers)

 (Attorney-in-fact for SCE Directors and Officers)

 Date:
 Date: