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			December 31, 2020
☐			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

EDISON INTERNATIONAL

California

95-4137452

1-2313

SOUTHERN CALIFORNIA EDISON COMPANY

California

95-1240335

EDISON INTERNATIONAL

SOUTHERN CALIFORNIA EDISON COMPANY

2244 Walnut Grove Avenue

2244 Walnut Grove Avenue

(P.O. Box 976)

(P.O. Box 800)

Rosemead,

California

91770

Rosemead,

California

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:

Edison International:

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.

    Edison International        Yes ☑ No ☐    Southern California Edison Company        Yes ☑ No ☐

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.

    Edison International        Yes ☐ No ☑    Southern California Edison Company        Yes ☐ No ☑

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.

    Edison International        Yes ☑ No ☐    Southern California Edison Company        Yes ☑ No ☐

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).

    Edison International        Yes ☑ No ☐    Southern California Edison Company        Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-12 of the Exchange Act. (Check One):

Edison International

Large Accelerated Filer

Accelerated Filer

Non-accelerated Filer

Smaller Reporting Company

Emerging growth company

☑

☐

☐

☐

☐

Southern California Edison 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.
Edison International			☐			Southern California Edison Company			☐

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.
Edison International			☑			Southern California Edison Company			☐

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

    Edison International        Yes ☐ No ☑    Southern California Edison Company        Yes ☐ No ☑

Aggregate market value of voting and non-voting common equity held by non-affiliates of the registrants as of June 30, 2020, the last business day of the most recently completed second fiscal quarter:

    Edison International    Approximately $20.5 billion    Southern California Edison Company    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 18, 2021:
Edison International						379,283,328			shares
Southern California Edison Company						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 that General Instruction.

DOCUMENTS INCORPORATED BY REFERENCE

Designated portions of the Edison International Proxy Statement relating to Edison International's 2021 Annual Meeting of Shareholders are incorporated by reference into Part III of this report.

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TABLE OF CONTENTS

															SEC Form 10-K Reference Number
GLOSSARY												vi
FORWARD-LOOKING STATEMENTS												1
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS												3			Part II, Item 7
			MANAGEMENT OVERVIEW									3
			Highlights of Operating Results									3
			Southern California Wildfires and Mudslides									5
			COVID-19									9
			2021 General Rate Case									9
			Wildfire Mitigation, Wildfire Insurance and Restoration Expenses									10
			Electricity Industry Trends									11
			Capital Program									11
			RESULTS OF OPERATIONS									13
			Southern California Edison Company									13
						Impact of 2018 GRC						13
						Years ended December 31, 2020, 2019 and 2018						14
						Earning Activities						15
						Cost-Recovery Activities						16
						Supplemental Operating Revenue Information						16
						Income Taxes						16
			Edison International Parent and Other									17
						Loss from Operations						17
			LIQUIDITY AND CAPITAL RESOURCES									17
			Southern California Edison Company									17
						Available Liquidity						19
						Regulatory Proceedings						19
						Capital Investment Plan						22
						Decommissioning of San Onofre						24

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						SCE Dividends						25
						Margin and Collateral Deposits						26
						Regulatory Balancing and Memorandum Accounts						27
			Edison International Parent and Other									27
						Net Operating Loss and Tax Credit Carryforwards						28
			Historical Cash Flows									28
						Southern California Edison Company						28
						Edison International Parent and Other						32
			Contractual Obligations and Contingencies									33
						Contractual Obligations						33
						Contingencies						34
			Off-Balance Sheet Arrangements									34
			Environmental Developments									34
			MARKET RISK EXPOSURES									34
			Interest Rate Risk									34
			Commodity Price Risk									34
			Credit Risk									35
			CRITICAL ACCOUNTING ESTIMATES AND POLICIES									35
			Rate Regulated Enterprises									35
			Accounting for Contingencies									36
			Income Taxes									37
			Nuclear Decommissioning – Asset Retirement Obligation									38
			Pensions and Postretirement Benefits Other than Pensions									39
			Contributions to the Wildfire Insurance Fund									41
			NEW ACCOUNTING GUIDANCE									41
RISK FACTORS												42			Part I, Item 1A
			RISKS RELATING TO EDISON INTERNATIONAL									42
			RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY									42

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			Regulatory and Legislative Risks									42
			Operating Risks									44
			Financing Risks									47
			Competitive and Market Risks									47
			Cybersecurity and Physical Security Risks									48
			RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY									48
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK												49			Part II, Item 7A
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA												49			Part II, Item 8
			REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM									50
			CONSOLIDATED FINANCIAL STATEMENTS									56
			Consolidated Statements of Income for Edison International									56
			Consolidated Statements of Comprehensive Income for Edison International									57
			Consolidated Balance Sheets for Edison International									58
			Consolidated Statements of Cash Flows for Edison International									60
			Consolidated Statements of Changes in Equity for Edison International									61
			Consolidated Statements of Income for Southern California Edison Company									63
			Consolidated Statements of Comprehensive Income for Southern California Edison Company									63
			Consolidated Balance Sheets for Southern California Edison Company									64
			Consolidated Statements of Cash Flows for Southern California Edison Company									66
			Consolidated Statements of Changes in Equity for Southern California Edison Company									67
			NOTES TO CONSOLIDATED FINANCIAL STATEMENTS									68
			Note 1. Summary of Significant Accounting Policies									68
			Note 2. Property, Plant and Equipment									80
			Note 3. Variable Interest Entities									81
			Note 4. Fair Value Measurements									82
			Note 5. Debt and Credit Agreements									86
			Note 6. Derivative Instruments									88
			Note 7. Revenue									90

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			Note 8. Income Taxes									91
			Note 9. Compensation and Benefit Plans									95
			Note 10. Investments									109
			Note 11. Regulatory Assets and Liabilities									109
			Note 12. Commitments and Contingencies									113
			Note 13. Leases									126
			Note 14. Equity									129
			Note 15. Accumulated Other Comprehensive Loss									131
			Note 16. Other Income									131
			Note 17. Supplemental Cash Flows Information									132
			Note 18. Related-Party Transactions									132
			Note 19. Quarterly Financial Data (Unaudited)									133
SELECTED FINANCIAL DATA												134			Part II, Item 6
CONTROLS AND PROCEDURES												135			Part II, Item 9A
OTHER INFORMATION												135			Part II, Item 9B
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE												135			Part II, Item 9
BUSINESS												136			Part I, Item 1
			CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION									136
			Subsidiaries of Edison International									136
			Regulation of Edison International as a Holding Company									137
			Human Capital									137
			Insurance									139
			SOUTHERN CALIFORNIA EDISON COMPANY									139
			Regulation									139
			Overview of Ratemaking Process									140
			Purchased Power and Fuel Supply									142
			Competition									143
			Properties									144

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			Seasonality									145
			ENVIRONMENTAL CONSIDERATIONS									145
			Greenhouse Gas Regulation									145
			Environmental Risks									146
UNRESOLVED STAFF COMMENTS												146			Part I, Item 1B
PROPERTIES												146			Part I, Item 2
LEGAL PROCEEDINGS												147			Part I, Item 3
			2017/2018 Wildfire/Mudslide Events									147
			Environmental Proceedings									147
MINE SAFETY DISCLOSURES												147			Part I, Item 4
CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL												148
			INFORMATION ABOUT OUR EXECUTIVE OFFICERS									148			Part I
			DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE									149			Part III, Item 10
			EXECUTIVE COMPENSATION									149			Part III, Item 11
			CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE									149			Part III, Item 13
			SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS									149			Part III, Item 12
PRINCIPAL ACCOUNTANT FEES AND SERVICES												149			Part III, Item 14
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES												150			Part II, Item 5; Part III, Item 12
			Edison International									150
			Southern California Edison Company									150
			Comparison of Five-Year Cumulative Total Return									151
FORM 10-K SUMMARY												152			Part IV, Item 16
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES												152			Part IV, Item 15
			Exhibit Index									153
			Schedules Supplementing Financial Statements									157
SIGNATURES												164

This is a combined Form 10-K separately filed by Edison International and Southern California Edison Company. Information contained herein relating to an individual company is filed by such company on its own behalf. Each company makes representations only as to itself and makes no other representation whatsoever as to any other company.

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GLOSSARY

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

2017/2018 Wildfire/Mudslide Events			the Thomas Fire, the Koenigstein Fire, the Montecito Mudslides and the Woolsey Fire, collectively
2019/2020 Wildfires			wildfires that originated in Southern California in 2019 and 2020 where SCE's equipment may be alleged to be associated with the fire's ignition
AB 1054			California Assembly Bill 1054, executed by the governor of California on July 12, 2019
AB 1054 Excluded Capital Expenditures			approximately $1.6 billion in wildfire risk mitigation capital expenditures that SCE will exclude 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 in the year of the applicable prudency determination
ARO(s)			asset retirement obligation(s)
BRRBA			Base Revenue Requirement Balancing Account
CAISO			California Independent System Operator
Capital Structure Compliance Period			January 1, 2020 to December 31, 2022, 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
CEMA			Catastrophic Event Memorandum Accounts
COVID-19			Coronavirus disease 2019
CPUC			California Public Utilities Commission
CSRP			Customer Service Re-platform, a SCE project to implement a new customer service system
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
Edison Energy			Edison Energy, LLC, a wholly-owned subsidiary of Edison Energy Group that is engaged in the competitive business of providing data-driven energy solutions to commercial, institutional and industrial customers
Edison Energy Group			Edison Energy Group, Inc., a wholly-owned subsidiary of Edison International, that is a holding company for subsidiaries engaged in competitive businesses
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 22, 2021
EEI Serious Injuries			a work-related injury that is categorized as a “serious injury” by Edison Electric Institute, which includes injuries that meet any of the following “serious” criteria: amputations (involving bone); concussions and/or cerebral hemorrhages; injury to internal organs; bone fractures excluding fingers and toes, compound bone fractures for fingers and toes; tendon and ligament tears; herniated disks (neck or back); lacerations resulting in severed tendons and/or a deep wound requiring internal stitches; second or third degree burns; eye injuries resulting in eye damage or loss of vision; injections of foreign materials; severe heat exhaustion and all heat stroke; and dislocation of a major joint
EEI SIF			a work-related fatality or an EEI Serious Injury
Electric Service Provider			an entity that offers electric power and ancillary services to retail customers, other than electrical corporations (like SCE) and CCAs
ERRA			Energy Resource Recovery Account
FERC			Federal Energy Regulatory Commission
FERC 2019 Settlement Period			November 12, 2019 through at least December 31, 2021

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FHPMA			Fire Hazard Prevention Memorandum Account
Fitch			Fitch Ratings, Inc.
GAAP			generally accepted accounting principles
GHG			greenhouse gas
GRC			general rate case
GS&RP			Grid Safety and Resiliency Program
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
kV			unit of electrical potential equal to 1000 volts
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.
NEM			net energy metering
NERC			North American Electric Reliability Corporation
NRC			Nuclear Regulatory Commission
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)
PCIA			Power Charge Indifference Adjustment
PG&E			Pacific Gas & Electric Company
PSPS			Public Safety Power Shutoffs
ROE			return on common equity
RPS			renewables portfolio standard
S&P			Standard & Poor's Financial Services LLC
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
SEC			U.S. Securities and Exchange Commission
SED			Safety and Enforcement Division of the CPUC
SoCalGas			Southern California Gas Company
SoCore Energy			SoCore Energy LLC, a former subsidiary of Edison Energy Group that was sold in April 2018
Tax Reform			Tax Cuts and Jobs Act signed into law on December 22, 2017
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 Subrogation Plaintiffs			the plaintiffs party to the TKM Subrogation Settlement, representing all the insurance subrogation plaintiffs in the TKM litigation
TKM Subrogation Settlement			a settlement entered into by Edison International and SCE in September 2020 in the TKM litigation to which the TKM Subrogation Plaintiffs are party
Turnover Rate			the number of employees (other than interns) who leave the companies for voluntary or involuntary reasons, excluding death, divided by the average number of employees during the relevant period.
US EPA			U.S. Environmental Protection Agency
VCFD			Ventura County Fire Department

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WEMA			Wildfire Expense Memorandum Account
WMP			a wildfire mitigation plan required to be filed at least once every three years 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
Woolsey Subrogation Plaintiffs			the plaintiffs party to the Woolsey Subrogation Settlement, representing all the insurance subrogation plaintiffs in the Woolsey Fire litigation at the time of the settlement
Woolsey Subrogation Settlement			a settlement entered into by Edison International and SCE in January 2021 in the Woolsey litigation to which the Woolsey Subrogation Plaintiffs are party
WSD			Wildfire Safety Division of the CPUC

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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," 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, including uninsured wildfire-related and debris flow-related costs, costs incurred to mitigate the risk of utility equipment causing future wildfires, costs incurred to implement SCE's new customer service system and costs incurred as a result of the COVID-19 pandemic;

•ability of SCE to implement its WMP;

•risks of regulatory or legislative restrictions that would limit SCE’s ability to implement PSPS when conditions warrant or would otherwise limit SCE’s operational PSPS practices;

•risks associated with implementing PSPS, including regulatory fines and penalties, claims for damages and reputational harm;

•ability of SCE to maintain a valid safety certification;

•ability to obtain sufficient insurance at a reasonable cost, including insurance relating to SCE's nuclear facilities and wildfire-related claims, and to recover the costs of such insurance or, in the event liabilities exceed insured amounts, the ability to recover uninsured losses from customers or other parties;

•extreme weather-related incidents (including events caused, or exacerbated, by climate change, such as wildfires, debris flows, high wind events and extreme heat events) and other natural disasters (such as earthquakes), which could cause, among other things, public safety issues, property damage, operational issues (such as rotating outages and issues due to damaged infrastructure), PSPS activations and unanticipated costs;

•risks associated with AB 1054 effectively mitigating the significant risk 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 new prudency standard established under AB 1054;

•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, 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, and delays in executive, regulatory and legislative actions;

•ability of Edison International or SCE to borrow funds and access bank and capital markets on reasonable terms;

•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, delays, contractual disputes, and cost overruns;

•pandemics, such as COVID-19, and other events that cause regional, statewide, national or global disruption, which could impact, among other things, Edison International's and SCE's business, operations, cash flows, liquidity and/or financial results and cause Edison International and SCE to incur unanticipated costs;

•physical security of Edison International's and SCE's critical assets and personnel and the cybersecurity of Edison International's and SCE's critical information technology systems for grid control, and business, employee and customer data;

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•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;

•risks inherent in SCE's transmission and distribution infrastructure investment program, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, power curtailment costs (payments due under power contracts in the event there is insufficient transmission to enable acceptance of power delivery), changes in the CAISO's transmission plans, and governmental approvals;

•risks associated with the operation of transmission and distribution assets and power generating facilities, including worker 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;

•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 and effective tax rate;

•changes in future taxable income, or changes in tax law, that would limit Edison International's and SCE's realization of expected net operating loss and tax credit carryover benefits prior to expiration;

•changes in the fair value of investments and other assets;

•changes in interest rates and rates of inflation, including escalation rates (which may be adjusted by public utility regulators);

•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 Council, and similar regulatory bodies in adjoining regions, and changes in the United States' and California's environmental priorities that lessen the importance the state places on GHG reduction;

•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;

•cost and availability of labor, equipment and materials;

•potential for penalties or disallowance for non-compliance with applicable laws and regulations; 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 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 other information that may be of interest to investors in a section titled "Events and Presentations" at www.edisoninvestor.com in order to publicly disseminate such information.

Except when otherwise stated, references to each of Edison International, SCE, or Edison Energy Group mean each such company with its subsidiaries on a consolidated basis. References to "Edison International Parent and Other" mean Edison International Parent and its consolidated competitive 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.

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

The discussion related to the results of operations and changes in financial condition for 2019 compared to 2018 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, 2019, which was filed with the SEC in February 2020.

MANAGEMENT OVERVIEW

Highlights of Operating Results

Edison International is the parent holding company of SCE and Edison Energy Group. 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 of southern California. Edison Energy Group is a holding company for Edison Energy which is engaged in the competitive business of providing data-driven energy solutions to commercial, institutional and industrial customers. Edison Energy's business activities are currently not material to report as a separate business segment.

(in millions)			2020						2019						2020 vs 2019 Change						2018
Net income (loss) attributable to Edison International
Continuing operations
SCE			$	810					$	1,409					$	(599)					$	(310)
Edison International Parent and Other			(71)						(125)						54						(147)
Discontinued operations			—						—						—						34
Edison International			739						1,284						(545)						(423)
Less: Non-core items
SCE
2017/2018 Wildfire/Mudslide Events claims and expenses, net of recoveries			(899)						(157)						(742)						(1,825)
Wildfire Insurance Fund expense			(242)						(109)						(133)						—
Disallowed historical capital expenditures in SCE's 2018 GRC decision			—						(123)						123						—
Sale of San Onofre nuclear fuel			108						8						100						9
Re-measurement of tax assets and liabilities			18						88						(70)						66
Edison International Parent and Other
Sale of Vidalia lease			96						—						96						—
Goodwill impairment			(25)						(18)						(7)						—
Sale of SoCore Energy and other			—						—						—						(46)
Re-measurement of tax liabilities			(3)						—						(3)						(12)
Discontinued operations			—						—						—						34
Total non-core items			(947)						(311)						(636)						(1,774)
Core earnings (losses)
SCE			1,825						1,702						123						1,440
Edison International Parent and Other			(139)						(107)						(32)						(89)
Edison International			$	1,686					$	1,595					$	91					$	1,351

Edison International's earnings are prepared in accordance with GAAP. Management uses core earnings (losses) internally for financial planning and for analysis of performance. Core earnings (losses) 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 (losses) are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (losses) 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

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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.

Edison International's 2020 earnings decreased $545 million, driven by a decrease in SCE's earnings of $599 million, partially offset by a decrease in Edison International Parent and Other losses of $54 million. SCE's lower net income consisted of $722 million of higher non-core losses, partially offset by $123 million of higher core earnings.

The increase in SCE's core earnings was primarily due to higher CPUC-related revenue due to the escalation mechanism as set forth in the 2018 GRC decision, lower expenses from regulatory deferrals related to 2020 wildfire mitigation activities and a 2020 adjustment to 2018 – 2019 regulatory deferrals from the approval of the GRC track 2 settlement. These increases were partially offset by the impact from the adoption of the 2018 GRC decision in the second quarter of 2019, higher employee benefits, higher customer uncollectibles from the COVID-19 pandemic and expenses from SCE's response to the pandemic that were unable to be deferred to regulatory assets.

Edison International Parent and Other's decrease in losses for 2020 was primarily due to higher non-core earnings of $86 million, partially offset by higher core losses of $32 million. The increase in core losses in 2020 was primarily due to higher interest expense as a result of increased borrowings.

Consolidated non-core items for 2020 and 2019 for Edison International included:

•Charges of $1.2 billion ($899 million after-tax) recorded in 2020 and $218 million ($157 million after-tax) recorded in 2019 for SCE's 2017/2018 Wildfire/Mudslide Events claims and expenses, net of expected recoveries from FERC customers.

•Charges of $336 million ($242 million after-tax) recorded in 2020 and $152 million ($109 million after-tax) recorded in 2019 from the amortization of SCE's contributions to the Wildfire Insurance Fund. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.

•Gains of $150 million ($108 million after-tax) recorded in 2020 and $11 million ($8 million after-tax) recorded in 2019 for SCE's sale of San Onofre nuclear fuel.

•Gain of $132 million ($96 million after-tax) recorded in 2020 for Edison International Parent and Other's sale of an investment in a lease of a hydroelectric power plant in Vidalia, Louisiana ("Vidalia Lease"). See "Notes to Consolidated Financial Statements—Note 13. Leases" for further information.

•Goodwill impairment charges of $34 million ($25 million after-tax) recorded in 2020 and $25 million ($18 million after-tax) recorded in 2019 for Edison International Parent and Other related to Edison Energy.

•An income tax benefit of $18 million and income tax expense of $3 million recorded in 2020 for SCE and Edison International Parent and Other, respectively, due to re-measurement of uncertain tax positions related to the 2010 – 2012 California state tax filings currently under audit.

•An impairment charge of $170 million ($123 million after-tax) recorded in 2019 for SCE related to disallowed historical capital expenditures in SCE's 2018 GRC final decision.

•Income tax benefits of $88 million recorded in 2019 for SCE related to changes in the allocation of deferred tax re-measurement between customers and shareholders as a result of a CPUC resolution issued in February 2019 to provide guidance on the implementation of Tax Reform. The resolution determined that customers are only entitled to excess deferred taxes which were included when setting rates and other deferred tax re-measurement belongs to shareholders.

See "Results of Operations" for discussion of SCE and Edison International Parent and Other results of operations.

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Southern California Wildfires and Mudslides

Wildfires in SCE's territory, including those where SCE's equipment may be alleged to be associated with the fire's ignition, have caused loss of life and substantial damage in recent years. Multiple factors have contributed to increased wildfire activity and faster progression of wildfires across SCE's service territory and in other areas of California. 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 wildfires. SCE has determined that approximately 27% of its service territory is in areas identified as high fire risk.

California has experienced unprecedented weather conditions in recent years and SCE's service territory remains susceptible to additional wildfire activity in 2021 and beyond. The worsening conditions across California increase the likelihood of wildfires, including those where SCE's equipment may be alleged to be associated with the fire's ignition. In response to worsening weather and fuel conditions and increased wildfire activity over the past several years, SCE has developed and is implementing its 2020 – 2022 WMP to reduce the risk of SCE equipment contributing to the ignition of wildfires. In addition, California has increased its investment in wildfire suppression capabilities.

In addition to the investments SCE is making through its WMP, SCE also uses its PSPS program to proactively de-energize power lines 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, impacting an aggregate of approximately 140,000 unique customers. In January 2021, the President of the CPUC sent SCE a letter expressing her concern regarding SCE's execution of PSPS in 2020 and notifying SCE that it must implement a PSPS action plan to reduce the impacts of PSPS on the customers and communities it serves. On a risk-informed basis, SCE is making efforts to reduce the frequency and impacts of PSPS in 2021 as compared to 2020, assuming that weather patterns in 2021 are similar to those experienced in 2020. SCE may be subject to mandated changes to, or restrictions on, its operational PSPS practices, regulatory fines and penalties, claims for damages and reputational harm if SCE does not execute PSPS in compliance with applicable rules and regulations or if it is determined that SCE has placed excessive reliance on PSPS.

Edison International and SCE have incurred material losses in connection with the 2017/2018 Wildfire/Mudslide Events described below. Several wildfires have originated in Southern California subsequent to 2018, however, Edison International and SCE expect that any losses incurred in connection with these fires will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such losses after insurance recoveries will not be material.

Edison International and SCE accrued estimated losses of $1,328 million in 2020 for wildfire-related claims, net of expected insurance recoveries. The 2020 charge consists of an increase in estimated losses for claims related to the 2017/2018 Wildfire/Mudslide Events of $1,297 million, against which SCE has recorded expected recoveries through FERC electric rates of $84 million. The resulting charge was $1,213 million ($874 million after-tax). The 2020 charge also includes $31 million ($21 million after FERC recovery and after-tax) of expenses primarily associated with self-insured retention related to the 2019/2020 Wildfires.

2017/2018 Wildfire/Mudslide Events

Wildfires in SCE's territory 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 VCFD and California Department of Forestry and Fire Protection ("CAL FIRE"), have determined that the largest of the 2017 fires in SCE's territory originated on December 4, 2017, in the Anlauf Canyon area of Ventura County (the investigating agencies refer to this fire as the "Thomas Fire"), followed shortly thereafter by the Koenigstein Fire. The December 4, 2017 fires eventually burned substantial acreage in both Ventura and Santa Barbara Counties. The largest of the November 2018 fires in SCE's territory, known as the Woolsey Fire, originated in Ventura County and burned acreage in both Ventura and Los Angeles Counties.

In March 2019, the VCFD and CAL FIRE jointly issued separate reports finding that the Thomas Fire and the Koenigstein Fire were each caused by SCE equipment. At this time, based on available information, SCE has not determined whether its equipment caused the Thomas Fire. Based on publicly available radar data showing a smoke plume in the Anlauf Canyon area emerging in advance of the start time of the Thomas Fire indicated in the Thomas Fire report, SCE believes that the Thomas Fire started at least 12 minutes prior to any issue involving SCE's system and at least 15 minutes prior to the start time indicated in the report. SCE has previously disclosed that SCE believed its equipment was associated with the ignition of the Koenigstein Fire. SCE is continuing to assess the extent of damages that may be attributable to the Thomas Fire and the Koenigstein Fire.

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SCE has received a non-final redacted draft of a report from the VCFD which states that the VCFD investigation team determined that electrical equipment owned and operated by SCE was the cause of the Woolsey Fire. Absent additional evidence, SCE believes that it is likely that its equipment was associated with the ignition of 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 the Montecito Mudslides that occurred 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.

Under the terms of the TKM Subrogation Settlement that Edison International and SCE entered into in the third quarter of 2020, all of the TKM Subrogation Plaintiffs' collective claims arising from the Thomas Fire, Koenigstein Fire or Montecito Mudslides have been resolved. Under the terms of the TKM Subrogation Settlement, SCE has paid the TKM Subrogation Plaintiffs an aggregate of $1.2 billion and also agreed to pay $0.555 for each dollar in claims to be paid by the TKM Subrogation Plaintiffs to their policy holders on or before July 15, 2023, up to an agreed upon cap. In 2020 SCE also entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $300 million to those individual plaintiffs.

At December 31, 2019, Edison International and SCE were unable to determine a best estimate of expected losses within a reasonably estimated range and therefore Edison International's and SCE's consolidated balance sheets included estimated losses, established at the lower end of the reasonably estimated range of expected losses, of $4.5 billion for the 2017/2018 Wildfire/Mudslide Events. In light of the TKM Subrogation Settlement and increased settlement activity with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation, among other things, management established a best estimate of expected potential losses for alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events litigation in the third quarter of 2020. As a result, Edison International and SCE recorded a charge of $1.3 billion in September 2020 related to the 2017/2018 Wildfire/Mudslide Events, against which SCE recorded expected recoveries through FERC electric rates of $84 million. The resulting net pre-tax charge to earnings was $1.2 billion ($874 million after-tax).

Through December 31, 2020, Edison International and SCE have recorded total pre-tax charges of $6.2 billion, expected recoveries from insurance of $2.0 billion and expected recoveries through FERC electric rates of $233 million related to the 2017/2018 Wildfire/Mudslide Events. The after-tax net charges to earnings recorded through December 31, 2020 have been $2.9 billion.

As of December 31, 2020, SCE had paid $1.8 billion under settlements related to the 2017/2018 Wildfire/Mudslide Events, of which $1.3 billion has been recovered through insurance and $144 million has been recovered through FERC-jurisdictional electric rates.

In January 2021, Edison International and SCE entered into the Woolsey Subrogation Settlement with the Woolsey Subrogation Plaintiffs to resolve those parties' collective claims arising from the Woolsey Fire. Under the terms of the Woolsey Subrogation Settlement, SCE agreed to pay the Woolsey Subrogation Plaintiffs an aggregate of $2.2 billion by April 22, 2021. SCE has also agreed to pay $0.67 for each dollar in claims to be paid by the Woolsey Subrogation Plaintiffs to their policy holders on or before July 15, 2023, up to an agreed upon cap. Between December 31, 2020 and February 18, 2021, SCE also entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $80 million to those individual plaintiffs. After giving effect to all settlements entered into through February 18, 2021, Edison International and SCE's best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events will be $2.1 billion.

The remaining estimated losses for the 2017/2018 Wildfire/Mudslide Events do not include an estimate of any potential fines or penalties that could be levied against SCE in connection with the 2017/2018 Wildfire/Mudslide Events. Edison International and SCE are currently unable to reasonably estimate the magnitude of any such fines or penalties, or the associated timing if they were to be imposed. 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 as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of the 2017/2018 Wildfire/Mudslide Events, the complexities associated with fires that merge, whether inverse condemnation will be held applicable to SCE with respect to damages caused by the Montecito Mudslides, the preliminary nature of the litigation processes, the uncertainty in estimating damages that may be alleged, and the uncertainty as to how these factors impact future settlements.

SCE will seek CPUC-jurisdictional rate recovery of prudently-incurred, actual losses realized in connection with the 2017/2018 Wildfire/Mudslide Events in excess of available insurance. SCE believes that, in light of the CPUC's decision in a

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cost recovery proceeding involving SDG&E arising from several 2007 wildfires in SDG&E's service area, there is substantial uncertainty regarding how the CPUC will interpret and apply its prudency standard to an investor-owned utility in future wildfire cost-recovery proceedings for fires ignited prior to July 12, 2019. Accordingly, while the CPUC has not made a determination regarding SCE's prudency relative to any of the 2017/2018 Wildfire/Mudslide Events, SCE is unable to conclude, at this time, that uninsured CPUC-jurisdictional wildfire-related costs are probable of recovery through electric rates.

Current Wildfire Insurance Coverage

SCE has approximately $1.0 billion of wildfire-specific insurance coverage for events that may occur during the period July 1, 2020 through June 30, 2021, subject to up to $80 million of co-insurance and $50 million of self-insured retention, which results in net coverage of approximately $870 million. Various coverage limitations within the policies that make up SCE's wildfire insurance coverage could result in additional material self-insured costs, for instance in the event of multiple wildfire occurrences during a policy period. SCE believes that its insurance coverage for the July 1, 2020 through June 30, 2021 period meets its obligation to maintain reasonable insurance coverage under AB 1054.

2019 Wildfire Legislation

In July 2019, AB 1054 was signed by the governor of California and became effective immediately. The summary of the wildfire legislation in this report is based on SCE's interpretation of the legislation and is qualified in its entirety by, and should be read together with, AB 1054 and companion Assembly Bill 111.

AB 1054 Prudency Standard

Under AB 1054, the CPUC must apply a new standard 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. 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 reasonable. 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 standard will survive the termination of the Wildfire Insurance Fund (described below).

Utilities participating in the Wildfire Insurance Fund are not required to reimburse the fund for amounts withdrawn from the fund that the CPUC finds were prudently incurred and can recover such prudently incurred 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 utility for payment of third-party damage 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 to have been caused by a utility.

SCE and SDG&E collectively made their initial contributions totaling approximately $2.7 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 to the Wildfire Insurance Fund through annual contributions to the fund over a 10-year period, of which they have made two annual contributions totaling approximately $600 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.

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Through December 31, 2020, SCE has contributed approximately $2.6 billion to the Wildfire Insurance Fund and has committed to make eight annual contributions of approximately $95 million per year to the fund, by no later than January 1 of each year. Edison International supported SCE's initial contribution of $2.4 billion to the Wildfire Insurance Fund by raising $1.2 billion from the issuance of Edison International equity. SCE raised the remaining $1.2 billion from the issuance of long-term debt. SCE's contributions to the Wildfire Insurance Fund will not be 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.

Reimbursement from Wildfire Insurance Fund and AB 1054 Liability Cap

Participating investor-owned utilities will be reimbursed from the Wildfire Insurance Fund for eligible claims, 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, in some instances, to the AB 1054 Liability Cap. A utility will not be eligible for the AB 1054 Liability Cap if it does not maintain a valid safety certification or its actions or inactions that resulted in the wildfire are found to constitute conscious or willful disregard of the rights and safety of others. Based on SCE's forecasted weighted-average 2021 rate base and using the equity portion of SCE's CPUC authorized capital structure of 52%, SCE's requirement to reimburse the Wildfire Insurance Fund for eligible claims disallowed in 2021 would be capped at approximately $3.2 billion. 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 the submission of certain required safety information, including an approved WMP. On September 17, 2020, SCE obtained a safety certification that will be valid for 12 months. Notwithstanding its 12-month term, if SCE requests a new safety certification prior to the expiration of its current safety certification, then its current safety certification will remain valid until the WSD acts on SCE's request for a new safety certification.

Under AB 1054, SCE is required to submit a WMP to the CPUC at least once every three years for review and approval. Beginning in 2020, each such plan was required to cover at least a three-year period. SCE filed its 2020 – 2022 WMP in February 2020. In June 2020, the CPUC ratified the WSD's conditional approval of SCE's 2020 – 2022 WMP. The approval is conditioned on SCE providing requested information to the WSD, including additional descriptions of how SCE is implementing, and will implement, certain requirements imposed by the WSD. SCE filed an update to its 2020 – 2022 WMP on February 5, 2021 to, among other things, report on implementation of its plan in 2020 and describe new and ongoing wildfire mitigation activities.

Capital Expenditure Requirement

Under AB 1054, approximately $1.6 billion of spending by SCE on wildfire risk mitigation capital expenditures made after August 1, 2019, cannot be included in the equity portion of SCE's rate base. SCE can apply for irrevocable orders from the CPUC to finance these AB 1054 Excluded Capital Expenditures, including through the issuance of securitized bonds, and can recover any prudently incurred financing costs. In November 2020, the CPUC issued an irrevocable order permitting SCE to finance approximately $340 million, comprised of AB 1054 Excluded Capital Expenditures incurred in connection with GS&RP and prudently incurred financing costs, through the issuance of securitized bonds. As of December 31, 2020, SCE has spent $1.3 billion on AB 1054 Excluded Capital Expenditures and expects to spend the remainder of the AB 1054 Excluded Capital Expenditures in the first quarter of 2021. SCE issued securitized bonds in the amount of $338 million in February 2021 and expects to seek additional irrevocable orders from the CPUC to finance the remaining AB 1054 Excluded Capital Expenditures.

For further information, 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" and "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

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COVID-19

The COVID-19 pandemic is having a significant impact on global society and economies. As a result of the pandemic, Edison International and SCE have experienced increased costs, but the pandemic has not had a pervasive impact on SCE's or Edison International's ability to operate their business. Edison International and SCE have taken steps to mitigate the impacts to operations, with all employees who, in the companies' assessment, can work remotely and perform their job functions effectively, directed to do so. Employees and contract workers designated by California as essential workers continue to work at SCE facilities or in the field to maintain operations and perform critical work to protect public safety and reduce the risk of wildfires. Edison International and SCE have modified work practices, provided personal protective equipment and provided additional employee benefits, among other measures, to reduce the impacts of the pandemic on their workforce.

Decoupling revenue mechanisms in California allow for differences in revenue resulting from actual and forecast volumetric electricity sales to be collected from or refunded to ratepayers and therefore insulate SCE's earnings from reductions in electricity usage. However, the CPUC has implemented certain measures to assist customers during the pandemic, including suspending service disconnections due to nonpayment for residential and small business customers, waiving late payment fees for business customers, and offering flexible payment plans for customers experiencing difficulty paying their electric bills. Accordingly, days outstanding on receivables and uncollectible accounts have increased.

In March 2020, the governor of California announced a statewide emergency as part of the state's response to address the COVID-19 pandemic. As a result, SCE established memorandum accounts with CPUC approval, effective March 2020, to track incremental costs associated with the emergency for recovery, subject to CPUC reasonableness reviews.

As a direct result of the pandemic, as of December 31, 2020, SCE has recognized net incremental costs of $191 million primarily related to increased estimates of customer uncollectibles, sequestering certain SCE employees at essential work locations and coordination of SCE's response to the emergency, $176 million has been deferred to memorandum accounts for future CPUC reasonableness review and $15 million has been transferred to balancing accounts pending recovery.

For further information see "Notes to the Consolidated Financial Statements—Note 11. Regulatory Assets and Liabilities" and "Risk Factors." Legislation was passed in California in September 2020 allowing for securitization of revenue shortfalls associated with the economic effects of the COVID-19 pandemic, subject to approval of a financing order by the CPUC.

2021 General Rate Case

The 2021 GRC consists of four separate tracks. Track 1 is similar to previous GRCs and addresses revenue requirements for the three-year period 2021 – 2023. Tracks 2 and 3 address the reasonableness of 2018 – 2019 and 2020 wildfire mitigation costs that were incremental to amounts authorized in the 2018 GRC, respectively. In January 2020, a CPUC decision introduced a third attrition year in current and future GRCs. As a result, track 4 will address the revenue requirement for 2024. SCE is scheduled to submit its testimony for track 4 in May 2022.

In January 2021, the CPUC approved a settlement between SCE and all the parties to track 2 of the 2021 GRC proceeding (collectively, the "Track 2 Parties"). As a result of the CPUC approval of the GRC track 2 settlement, an additional $41 million ($29 million after-tax) of operations and maintenance expenses were deferred in the fourth quarter of 2020 as probable of recovery. The revenue requirement under the settlement was $391 million. For more information on tracks 2 and 3 of the 2021 GRC, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings—2021 General Rate Case Wildfire Mitigation Memorandum Account Balances."

Track 1 of 2021 GRC

In the 2021 GRC, SCE has requested a test year revenue requirement of $7.6 billion, an approximately $1.3 billion increase over the 2020 revenue requirement authorized in the 2018 GRC as updated for post test-year ratemaking changes. SCE's request proposes post test-year increases in 2022 and 2023 of $452 million and $524 million, respectively. SCE's request excludes the revenue requirement associated with the approximately $1.6 billion of AB 1054 Excluded Capital Expenditures.

SCE's requested increase to its revenue requirement in the 2021 GRC application is largely due to SCE's efforts to reduce wildfire risk. Certain of SCE's key wildfire mitigation forecast expenditures are subject to significant potential volatility. As a result, SCE has proposed establishing two-way balancing accounts for wildfire mitigation-related enhanced vegetation management, inspection activities and grid hardening, as well as for insurance premiums.

The capital programs requested in SCE's 2021 GRC include the infrastructure and programs necessary to implement California's ambitious public policy goals, including wildfire mitigation, de-carbonization of the economy through electrification and integration of distributed energy resources across a rapidly modernizing grid. See "—Capital Program" for further details.

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In an amendment submitted in February 2020, SCE removed its CSRP implementation costs from the 2021 GRC. SCE will continue to track the cost of the CSRP implementation in a memorandum account previously approved in the 2018 GRC and seek recovery of the CSRP implementation costs in a future application to be filled with the CPUC.

In April and May 2020, intervenors to the 2021 GRC proceeding, including the CPUC Public Advocates Office ("Cal Advocates") and The Utility Reform Network ("TURN"), submitted testimony in response to SCE's August 2019 application as revised and amended. Cal Advocates proposed reductions to 2021 operation and maintenance spending of $423 million or 15% of the total, and reductions to 2021 capital spending of $445 million or 9% of the total. TURN proposed reductions to 2021 operation and maintenance spending of $556 million or 17% of the total, and reductions to 2021 capital spending of $714 million or 14% of the total. The reductions to capital expenditures proposed by both parties included significant proposed reductions to SCE's Wildfire Covered Conductor Program. If adopted, the proposals of Cal Advocates and TURN would result in a 2021 revenue requirement of approximately $6.9 billion and $6.7 billion, respectively.

SCE believes that receiving a proposed decision on track 1 of the 2021 GRC in the first quarter of 2021 in line with the CPUC’s schedule for track 1 is unlikely. The CPUC has approved the establishment of a memorandum account making the authorized revenue requirement changes effective January 1, 2021. 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 2020 authorized revenue requirement until a GRC decision is issued.

Wildfire Mitigation, Wildfire Insurance and Restoration Expenses

In response to the increase in wildfire activity, and faster progression of and increased damage from wildfires across SCE's service territory and throughout California, SCE is currently incurring wildfire mitigation, wildfire insurance and wildfire and drought restoration related spending at levels significantly exceeding amounts authorized in its 2018 GRC. Several regulatory mechanisms exist to allow SCE to track and seek recovery of these incremental costs through customer rates, or issuance of securitized bonds for AB 1054 Excluded Capital Expenditures. 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. For certain wildfire mitigation and wildfire insurance expenses SCE performs its assessment of future recovery after its year to date spending exceeds the amounts authorized for the full calendar year under its current revenue requirement.

As of December 31, 2020, SCE has recognized $886 million of regulatory assets related to incremental wildfire mitigation expenses, including depreciation expense from $1.6 billion of total incremental wildfire mitigation capital expenditures. Additionally, SCE has recognized $356 million of regulatory assets associated with drought and wildfire restoration and $212 million of regulatory assets related to incremental wildfire insurance expenses. 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. In 2020, the CPUC has approved recovery of certain incremental wildfire mitigation and wildfire insurance expenses through SCE's GS&RP and WEMA proceedings. The following table presents changes in wildfire-related and wildfire and drought restoration memorandum account balances in 2020:

(in millions)
Balance at December 31, 2019			$	868
Regulatory deferral			1,225
Less: approved for recovery and transferred to BRRBA			(628)
Balance at December 31, 20201			$	1,465

1     Includes interest expense of $11 million.

At December 31, 2020, the balance includes $405 million of expense approved for recovery in the GRC track 2 proceeding. In February 2021, SCE indicated its intent to seek a financing order from the CPUC to securitize the approved expense. In the event these costs are not authorized for securitization, SCE will include the costs in customer rates as soon as practicable.

For additional information, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings."

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Electricity Industry Trends

The electric power industry is undergoing transformative change driven by technological advances, such as customer-owned generation, electric vehicles and energy storage, which are altering the nature of energy generation and delivery. California is committed to reducing its GHG emissions, improving local air quality and supporting continued economic growth. The state set goals to reduce GHG emissions by 40% from 1990 levels by 2030 and 80% from the same baseline by 2050. Additionally, the state is aiming to be carbon neutral by 2045. State and local air quality plans call for substantial improvements. In the most polluted areas of the state this includes reducing smog-causing nitrogen oxides 90% below 2010 levels by 2032. While these policy goals cannot be achieved by the electric sector alone, the electric grid is a critical enabler of the adoption of new energy technologies that support California's climate change and GHG reduction objectives. Therefore, California has set RPS targets which require California retail sellers of electricity to provide 60% of energy sales from renewable resources by 2030. California also requires sellers of electricity to deliver 100% of retail sales from carbon free sources by 2045. In 2020 approximately 43% of SCE's customer deliveries came from carbon-free resources. SCE anticipates it will meet California's requirements through 2045.

The new federal administration has also signaled support for increased measures to respond to climate change and to achieve carbon neutrality by 2050 by having the United States rejoin the Paris Agreement in January 2021 and by issuing executive orders that aim to electrify federal fleets and set electric vehicle charging goals.

Edison International believes that California's 2045 goals can be achieved most economically through emissions reductions from using clean electricity serving 100% of retail sales, electrifying 76% of light-duty vehicles, 67% of medium-duty vehicles, 38% of heavy-duty vehicles, 85% of buses and 70% of buildings and using low-carbon fuels for technologies that are not yet viable for electrification. California has shown strong long-term support of transportation electrification. as shown by the approval of SCE’s Charge Ready 2 program and the Governor of California's September 2020 Executive Order banning sales of new gas vehicles by 2035.

To support these goals, 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 efficient electrification, building a modernized and more reliable grid, and enabling customers' technology choices. SCE is focused on improving the safety, reliability and resilience of the transmission and distribution network and enabling increased penetration of DERs, electric transportation, building electrification and energy efficiency programs. 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's focus on the transmission and distribution of electricity aligns with California's policy supporting competitive power procurement markets. For more information on the grid development, see "Liquidity and Capital Resources—SCE—Capital Investment Plan—Grid Development—Wildfire Mitigation" and "Liquidity and Capital Resources—SCE—Capital Investment Plan—Grid Development—Transportation Electrification."

Changes in the electric power industry are impacting customers and jurisdictions outside California as well. Edison International believes that other states will also pursue climate change and GHG reduction objectives and large commercial and industrial customers will continue to pursue cost reduction and sustainability goals. Edison Energy provides data-driven energy solutions to commercial, institutional and industrial customers who may be impacted by these changes. Edison Energy aims to provide energy solutions that address cost, carbon and complex choices for their customers.

To better engage in this broader transformation and provide a view of developments outside of SCE, Edison International has made several minority investments in emerging companies in areas related to the technology changes that are driving industry transformation and may make additional investments in the future. These investments are not financially material to Edison International.

Capital Program

Total capital expenditures (including accruals) were $5.5 billion in 2020 and $4.8 billion in 2019. SCE's year-end rate base was $34.7 billion at December 31, 2020 compared to $32.6 billion at December 31, 2019, after excluding rate base associated with AB 1054 Excluded Capital Expenditures of $875 million at December 31, 2020 and $252 million at December 31, 2019.

In connection with the 2021 GRC, SCE forecasts capital expenditures of $14.7 billion to $16.2 billion for 2021– 2023. In the absence of a 2021 GRC decision, SCE has developed, and is executing against, a 2021 capital expenditure plan that will allow SCE to meet what is ultimately authorized in the 2021 GRC decision while minimizing the associated risk of unauthorized spending.

The table below reflects capital expenditures for 2021 based on planned CPUC jurisdictional spending and current management expectations of FERC- jurisdictional spending. CPUC jurisdictional spending includes amounts requested in the

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2021 GRC, updated in rebuttal testimony, spending associated with SCE's wildfire mitigation-related capital expenditures under the GS&RP and WMP, and other non-GRC CPUC capital spending. The CPUC jurisdictional capital spending in 2022 and 2023 will be dependent upon the amount approved in a final 2021 GRC decision. Forecasted expenditures for FERC capital projects are subject to change due to timeliness of permitting, licensing, regulatory approvals, and contractor bids.

SCE's forecasted capital expenditures for 2021 include approximately $113 million of capital spending on the CSRP project. Total forecasted capital expenditures for the CSRP project are approximately $540 million from inception through 2021. In the 2021 GRC, SCE provided a cost estimate to the CPUC of $308 million in capital expenditures for the CSRP program. In February 2020, SCE filed an update with the CPUC to exclude CSRP implementation costs from rate base and capital expenditures of the 2021 GRC application and to defer review of the reasonableness of the capital expenditures to a future regulatory proceeding SCE expects to file in 2021.

Based on management judgment using historical precedent of previously authorized amounts and potential permitting delays and other operational considerations, a range case has been provided reflecting a 10% reduction on the total capital forecast over the three-year period, 2021 – 2023. The completion of projects, the timing of expenditures, and the associated cost recovery may be affected by permitting requirements and delays, construction schedules, availability of labor, equipment and materials, financing, legal and regulatory approvals and developments, community requests or protests, weather and other unforeseen conditions.

The following table sets forth a summary of capital expenditures for 2020 actual spend and a forecast for 2021 – 2023 on the basis described above:

(in billions)						2020			2021			2022			2023			Total 2021 – 2023
Traditional capital expenditures
Distribution						$	3.8		$	3.4		$	3.3		$	3.3		$	10.0
Transmission						0.7			0.7			0.7			0.6			2.0
Generation						0.2			0.2			0.2			0.2			0.6
Subtotal						4.7			4.3			4.2			4.1			12.6
Wildfire mitigation-related capital expenditures						0.8			1.2			1.1			1.3			3.6
Total capital expenditures						$	5.5		$	5.5		$	5.3		$	5.4		$	16.2
Total capital expenditures using range case discussed above						*			$	5.4		$	4.6		$	4.7		$	14.7

* Not applicable

SCE's authorized CPUC-jurisdictional rate base is determined through the GRC and other regulatory proceedings. Differences between actual and CPUC-authorized capital expenditures are addressed in subsequent GRC or other regulatory proceedings. FERC-jurisdictional rate base is generally determined based on actual capital expenditures.

Reflected below is SCE's weighted average annual rate base for 2020 – 2023 incorporating CPUC capital expenditures authorized in the 2018 GRC final decision, expected FERC capital expenditures, capital expenditures included in the 2021 GRC request and approved non-GRC projects or programs. The table below does not reflect the $1.3 billion of AB 1054 Excluded Capital Expenditures to December 31, 2020 or the planned $0.3 billion of such expenditures in 2021. The table below does not reflect rate base associated with non-GRC projects or programs that have not yet been approved by the CPUC, including CSRP and wildfire restoration costs. Inclusion of these in rate base will depend on the timing of regulatory approval. In addition, a third-party holds an option to invest up to $400 million in the West of Devers Transmission project at the estimated in-service date in May 2021. The rate base in the table below is reduced to reflect this option.

(in billions)						2020			2021			2022			2023
Rate base for expected capital expenditures						$	33.8		$	36.3		$	38.4		$	41.1
Rate base for expected capital expenditures (using range case described above)						*			$	36.2		$	37.6		$	39.5

* Not applicable

For additional information, see "Liquidity and Capital Resources—SCE—Capital Investment Plan."

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RESULTS OF OPERATIONS

SCE

SCE's results of operations are derived mainly through two sources:

•Earning activities – representing revenue authorized by the CPUC and the FERC which is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investment in generation, transmission and distribution assets. The annual revenue requirements are comprised of authorized operation and maintenance costs, depreciation, taxes and a return consistent with the capital structure. Also, included in earnings activities are revenue or penalties related to incentive mechanisms, other operating revenue and regulatory charges or disallowances.

•Cost-recovery activities – representing CPUC- and FERC-authorized balancing accounts which allow for recovery of specific project or program costs, subject to reasonableness review or compliance with upfront standards. Cost-recovery activities include rates which provide recovery, subject to reasonableness review of, among other things, fuel costs, purchased power costs, public purpose related-program costs (including energy efficiency and demand-side management programs) and certain operation and maintenance expenses. SCE earns no return on these activities.

Impact of 2018 GRC

In May 2019, the CPUC approved a decision in SCE's 2018 GRC. The revenue requirements in the 2018 GRC decision were retroactive to January 1, 2018. SCE recorded the prior period impact of the 2018 GRC decision in the second quarter of 2019 including an increase to earnings of $65 million attributable to 2018 from the application of the decision to revenue, depreciation expense and income tax expense, and an impairment of utility property, plant and equipment of $170 million ($123 million after-tax) related to disallowed historical capital expenditures.

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Years ended December 31, 2020, 2019 and 2018

The following table is a summary of SCE's results of operations for the periods indicated:

			2020									2019									2018
(in millions)			Earning Activities			Cost- Recovery Activities			Total Consolidated			Earning Activities			Cost- Recovery Activities			Total Consolidated			Earning Activities			Cost- Recovery Activities			Total Consolidated
Operating revenue			$	7,468		$	6,078		$	13,546		$	6,678		$	5,628		$	12,306		$	6,560		$	6,051		$	12,611
Purchased power and fuel			2			4,930			4,932			—			4,839			4,839			—			5,406			5,406
Operation and maintenance			2,280			1,243			3,523			2,073			863			2,936			1,972			730			2,702
Wildfire-related claims, net of insurance recoveries			1,328			—			1,328			255			—			255			2,669			—			2,669
Wildfire Insurance Fund expense			336			—			336			152			—			152			—			—			—
Depreciation and amortization			1,965			—			1,965			1,727			1			1,728			1,867			—			1,867
Property and other taxes			435			—			435			396			—			396			392			—			392
Impairment and other (income) expense			(150)			—			(150)			159			—			159			(12)			—			(12)
Other operating income			(1)			—			(1)			(4)			—			(4)			(7)						(7)
Total operating expenses			6,195			6,173			12,368			4,758			5,703			10,461			6,881			6,136			13,017
Operating income (loss)			1,273			(95)			1,178			1,920			(75)			1,845			(321)			(85)			(406)
Interest expense			(757)			(11)			(768)			(738)			(1)			(739)			(671)			(2)			(673)
Other income			149			106			255			119			76			195			107			87			194
Income (loss) before income taxes			665			—			665			1,301			—			1,301			(885)			—			(885)
Income tax benefit			(277)			—			(277)			(229)			—			(229)			(696)			—			(696)
Net income (loss)			942			—			942			1,530			—			1,530			(189)			—			(189)
Preferred and preference stock dividend requirements			132			—			132			121			—			121			121			—			121
Net income (loss) available for common stock			$	810		$	—		$	810		$	1,409		$	—		$	1,409		$	(310)		$	—		$	(310)
Net income (loss) available for common stock									$	810								$	1,409								$	(310)
Less: Non-core expense									(1,015)									(293)									(1,750)
Core earnings1									$	1,825								$	1,702								$	1,440

1    See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results."

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Earning Activities

2020 vs 2019

Earning activities were primarily affected by the following:

•Higher operating revenue of $790 million is primarily due to:

•An increase in CPUC-related revenue of $643 million primarily due to the 2018 GRC decision's escalation mechanism, the reduction to revenue in the second quarter of 2019 due to recording the 2018 impacts of the 2018 GRC decision and higher operating costs subject to balancing account treatment primarily as a result of the approval of the GS&RP balancing account.

•An increase in FERC-related revenue of $140 million primarily due to the $84 million of expected recoveries from customers for the FERC portion of wildfire-related claims in the third quarter of 2020 (see "Management Overview—Southern California Wildfires and Mudslides—2017/2018 Wildfire/Mudslide Events"), rate base growth and higher operating costs subject to balancing account treatment, partially offset by an increase in revenue in 2019 due to the settlement of SCE's 2018 FERC Formula Rate proceeding in 2019.

•Higher operation and maintenance expenses of $207 million primarily due to:

•Increased expenses of $149 million subject to balancing account treatment primarily as a result of the approval of the GS&RP balancing account.

•Higher employee benefit expenses of $51 million, including $39 million of incentive compensation partly associated with higher overtime and other supplemental wages, and other employee benefit programs.

•Increased expenses related to COVID-19 of $40 million, consisting of $16 million in labor and other expenses resulting from SCE’s response to the COVID-19 pandemic and $24 million of customer uncollectibles expense.

•The $25 million reduction to expenses recorded in the second quarter of 2019 primarily from the 2018 impact of adopting the 2018 GRC decision's change in capitalization rates.

•Higher wildfire insurance expenses of $21 million primarily due to the authorization to recover certain 2018 wildfire insurance expenses reducing expenses in 2019.

•Increased other expenses of $59 million including environmental remediation, worker's compensation and other support functions expenses.

•Decreased expenses of $97 million due to increased regulatory deferrals related to wildfire-mitigation costs including inspections, preventive maintenance and vegetation management costs. Although higher wildfire-mitigation costs were incurred in 2020, a higher proportion of these costs were deferred to wildfire mitigation memorandum accounts.

•Adjustment to 2018 – 2019 regulatory deferrals of $41 million as a result of the approval of CPUC for SCE's track 2 of the GRC proceeding. See "Management Overview—Wildfire Mitigation, Wildfire Insurance and Restoration Expenses" for further information.

•Charges of $1.3 billion and $255 million recorded in 2020 and 2019, respectively. The charges in 2020 and 2019 primarily relate to a change in estimated losses from wildfire-related claims related to the 2017/2018 Wildfire/Mudslide Events. Also included in the charges are $31 million and $23 million recorded by SCE in 2020 and 2019, respectively, primarily associated with self-insured retention expenses related to other wildfires. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

•Expenses of $336 million and $152 million recorded in 2020 and 2019, respectively, from amortization of Wildfire Insurance Fund contributions. See "Management Overview—Southern California Wildfires and Mudslides" for further information.

•Higher depreciation and amortization expense of $238 million primarily due to increased plant balances in 2020 and the 2018 impact of a change in depreciation rates and disallowed historical capital expenditures from adoption of the 2018 GRC decision, recorded in the second quarter of 2019.

•Higher property and other taxes of $39 million primarily due to higher property assessed values in 2020.

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•Impairment and other (income) expense primarily consists of a gain of $150 million in 2020 related to the sale of San Onofre nuclear fuel and an impairment charge in 2019. Under the terms of the January 2018 settlement of the San Onofre Order Instituting Investigation proceeding, the gain on sale of the nuclear fuel will not be returned to customers. The loss of $159 million in 2019 is primarily due to an impairment charge of $170 million related to the disallowed historical capital expenditures as a result of the 2018 GRC decision in 2019, discussed above.

•Higher interest expense of $19 million primarily due to increased borrowings and lower capitalized interest.

•Higher other income of $30 million primarily due to higher insurance benefits.

•Higher income tax benefit of $48 million primarily due to the impact of lower pre-tax income, partially offset by a tax benefit of $80 million recorded in 2019 as a result of the 2018 GRC decision and an $88 million tax benefit recorded in 2019 related to changes in the allocation of deferred tax re-measurement between customers and shareholders.

•Higher preferred and preference stock dividends of $11 million primarily due to a loss on redemption of preferred securities in 2020.

Cost-Recovery Activities

2020 vs 2019

Cost-recovery activities were primarily affected by the following:

•Higher purchased power and fuel costs of $91 million primarily driven by higher power price and higher energy purchase volume, partially offset by lower contract amendment charges. In addition, CAISO issued invoices that revised FERC tariffs for interest costs associated with scheduling coordinator activities, resulting in a generation surcharge of $59 million reflected as an additional purchased power expense and a transmission refund of $66 million as a reduction in operation and maintenance expense.

•Higher operation and maintenance expenses of $380 million primarily driven by the authorization to recover 2018 through June 2020 wildfire insurance costs above GRC authorized that had been deferred as regulatory assets (see "Management Overview—Wildfire Mitigation, Wildfire Insurance and Restoration Expenses") and higher transmission access charges, partially offset by the CAISO refund of $66 million mentioned above.

•Higher interest expense of $10 million primarily driven by the authorization to recover financing costs associated with incremental 2018 through June 2020 wildfire insurance expenses.

•Higher other income of $30 million primarily driven by higher net periodic benefit income related to the non-service cost components for SCE's other post-retirement benefit plans. See "Notes to Consolidated Financial Statements—Note 9. Compensation and Benefit Plans" for further information.

Supplemental Operating Revenue Information

SCE's retail billed and unbilled revenue (excluding wholesale sales) was $12.5 billion, $11.4 billion and $11.7 billion for 2020, 2019 and 2018, respectively.

The 2020 revenue increase is primarily related to the 2018 GRC decision's escalation mechanism, the approval of the GS&RP balancing account, higher FERC revenue due to expected recoveries for the FERC portion of wildfire-related claims and higher cost-recovery activities related to authorization to recover 2018 – 2020 wildfire insurance costs that had been deferred as regulatory assets increasing expenses. See "—Cost-Recovery Activities" and "—Earnings Activities" for further details.

As a result of the CPUC-authorized decoupling mechanism, SCE earnings are not affected by changes in retail electricity sales (see "Business—SCE—Overview of Ratemaking Process").

Income Taxes

SCE's income tax benefit increased by $48 million in 2020 compared to 2019. The effective tax rates were (41.7)% and (17.6)% for 2020 and 2019, respectively. SCE's effective tax rate is below the federal statutory rate of 21% primarily due to the CPUC's ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences, which reverse over time. The accounting treatment for these temporary differences results in recording regulatory assets and liabilities for amounts that would otherwise be recorded to deferred income tax expense. The effective tax rate decrease in 2020 is primarily due to the impact of lower pre-tax income, partially offset by the absence of tax benefit from the adoption of the 2018 GRC final decision and the absence of the 2019 changes in the allocation of deferred tax re-measurement between customers and shareholders that resulted from a CPUC resolution.

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See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for a reconciliation of the federal statutory rate to the effective income tax rates.

Edison International Parent and Other

Results of operations for Edison International Parent and Other includes amounts from other subsidiaries that are not significant as a reportable segment as well as intercompany eliminations.

Loss from Operations

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

			Years ended December 31,
(in millions)			2020						2019									2018
Edison Energy Group and subsidiaries			$	(35)					$	(24)								$	(78)
Corporate expenses and other subsidiaries			(36)						(101)									(69)
Total Edison International Parent and Other			$	(71)					$	(125)								$	(147)
Less: Non-core items			$	68					$	(18)								$	(58)
Core losses1			$	(139)					$	(107)								$	(89)

1 See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results."

The loss from operations of Edison International Parent and Other decreased $54 million in 2020 compared to 2019 primarily due to gain of $132 million ($96 million after-tax) recorded in 2020 for the sale of the Vidalia Lease, partially offset by higher interest expense as a result of increased borrowings.

LIQUIDITY AND CAPITAL RESOURCES

SCE

SCE's ability to operate its business, fund capital expenditures and implement its business strategy is dependent upon its 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 and regulatory matters.

SCE's costs of accessing capital markets has increased due to the risks associated with wildfires in California. Wildfire activity and the COVID-19 pandemic may cause narrower access to, or further increased costs of accessing, bank and capital markets. For further details, see "Management Overview—COVID-19" and "—Available Liquidity."

In the next 12 months, SCE expects to fund its cash requirements through operating cash flows, capital market financings, and equity contributions from Edison International Parent, as needed. SCE also has availability under its credit facilities to fund cash requirements.

At December 31, 2020 SCE had spent approximately $1.3 billion of the total approximately $1.6 billion of AB 1054 Excluded Capital Expenditures, SCE expects to finance these amounts by issuing securitized bonds. In February 2021 SCE issued securitized bonds in the amount of $338 million. SCE expects to securitize the remaining balance of AB 1054 Excluded Capital Expenditures based on the timing of the CPUC approving wildfire mitigation capital expenditures and related financing costs. For further information, see "Management Overview—Southern California Wildfires and Mudslides." Prior to issuance of such bonds, SCE is using a term loan of $475 million and floating rate first and refunding mortgage bonds of $900 million to finance AB 1054 Excluded Capital Expenditures. Additionally, SCE has several credit facilities available to support its AB 1054 Excluded Capital Expenditures. For further information, see "—Available Liquidity."

SCE expects to issue additional debt to finance payments for future resolutions of claims related to the 2017/2018 Wildfire/Mudslide Events that exceed insurance. To enable SCE to issue the necessary debt and to allow Edison International and SCE to maintain investment grade credit ratings and based on SCE's best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events, Edison International anticipates issuing securities with up to $1.0 billion of equity content to invest in SCE, during 2021.

In the third quarter of 2020, SCE redeemed $120 million of cumulative preferred stock, which were all of the outstanding shares of SCE's preferred stock, and $180 million of SCE's Series G Preference Stock. For further details, see "Notes to

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Consolidated Financial Statements—Note 14. Equity." The redemption reduces the preferred equity component of SCE's capital structure from 9% to 5%, bringing it in line with the capital structure authorized in the 2020 Cost of Capital decision.

In January 2021, SCE issued $750 million and $150 million in first and refunding mortgage bonds due in 2051 and 2030, respectively. The proceeds were primarily used to repay SCE's commercial paper borrowings and for general corporate purposes.

SCE's long-term issuer credit ratings are at investment grade levels. However, during the third quarter of 2020, the S&P rating outlooks for all three investor-owned utilities in California were revised to negative due to unprecedented wildfire activity throughout California in August and September of 2020. SCE's ratings outlook from Moody's and Fitch has remained stable despite 2020 wildfire activity due to the reduced financial risk that wildfires pose to SCE following enactment of AB 1054. For further information, see "Management Overview—Southern California Wildfires and Mudslides."

The following table summarizes SCE's current, long-term issuer credit ratings and outlook from the major credit rating agencies:

Moody's

Fitch

S&P

Credit Rating

Baa2

BBB-

BBB

Outlook

Stable

Stable

Negative

SCE's credit ratings may be further 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 depleted by claims from catastrophic wildfires. The broad economic impacts of the COVID-19 pandemic may also affect SCE's credit ratings. For further information see "Management Overview—COVID-19" and "Risk Factors." 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 would require SCE to pay related liabilities or post additional collateral if SCE's credit rating were to fall below investment grade. Incremental collateral requirements for power procurement contracts resulting from a potential downgrade of SCE's credit rating to below investment grade are $31 million as of December 31, 2020. In addition, if SCE's credit rating falls below investment grade, it may 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 the downgrade occurs. Furthermore, if SCE was downgraded below investment grade, counterparties may also institute new collateral requirements for future transactions. For further details, see "—Margin and Collateral Deposits."

The cost of capital mechanism set by the CPUC could impact SCE's results of operations and cash flows. The benchmark value for the current mechanism is the 12-month, October 1, 2018 through September 30, 2019, average Moody’s Baa utility bond yield of 4.5%. If the difference between the benchmark and the average of the same index for the 12-month period to September 30, 2021 exceeds 100-basis points, SCE's CPUC-authorized ROE will be adjusted for 2022 by half the amount of the difference (up or down). If the mechanism is triggered SCE's costs of long-term debt and preferred equity will also be adjusted for 2022 to reflect the then current embedded costs and projected interest rates. The average Moody's Baa utility bond yield between October 1, 2020 and January 31, 2021 was 3.17%. SCE is required to file its next cost of capital application by April 2022 for rates effective beginning January 2023. For further information see "Business—SCE—Overview of Ratemaking Process."

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Available Liquidity

At December 31, 2020, SCE had cash on hand of $55 million.

The following table summarizes the status of SCE's credit facilities at December 31, 2020:

(in millions, except for rates)
Execution date			Termination date			LIBOR plus (bps)			Use of proceeds			Commitment			Outstanding borrowings			Outstanding letters of credit			Amount available
March 2020			March 2021			65			Finance a portion of the AB 1054 Capital Expenditures 1, 2			$	800		$	495		$	—		$	305
May 2020			May 2021			150			Undercollections related to COVID-19 and general corporate purposes			1,500			—			—			1,500
June 2019			May 2024			108			Support commercial paper borrowings and general corporate purposes 3			3,000			725			159			2,116
Total SCE:												$	5,300		$	1,220		$	159		$	3,921

1This credit facility may be extended for two 364-day periods, at the lenders' discretion. The aggregate maximum principal amount may be increased up to $1.1 billion, provided that additional lender commitments are obtained.

2SCE expects to securitize these borrowings as AB 1054 Excluded Capital Expenditures. SCE intends to secure, or extend, short-term debt financing where necessary until securitization is executed.

3The aggregate maximum principal amount under this revolving credit facility may be increased up to $4.0 billion, provided that additional lender commitments are obtained. The credit facility may be extended for one additional year with the lenders' approval.

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 bank and capital markets. As necessary, SCE will utilize its available liquidity, capital market financings, other borrowings or parent company contributions to SCE equity in order to meet its obligations as they become due, including costs related to the 2017/2018 Wildfire/Mudslide 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, 2020, SCE's debt to total capitalization ratio was 0.51 to 1.

At December 31, 2020, SCE was in compliance with all financial covenants that affect access to capital.

Regulatory Proceedings

Wildfire Related Regulatory Proceedings

Grid Safety and Resiliency Program

In April 2020, the CPUC approved a settlement agreement between SCE and certain parties to SCE's GS&RP proceeding. Under the settlement, SCE is authorized to spend approximately $599 million ($476 million capital) between 2018 and 2020. Upon approval by the CPUC in July 2020, SCE established a balancing account to track the difference between actual GS&RP costs and amounts authorized. SCE included the authorized revenue requirement, other than for $304 million of AB 1054 Excluded Capital Expenditures, in rates on October 1, 2020 and securitized the portion of AB 1054 Excluded Capital Expenditures. For further information, see "—SCE."

GS&RP capital expenditures through 2020 were $978 million, of which $502 million was above the authorized amount and will be subject to reasonableness review in track 3 of the 2021 GRC, described below. GS&RP incremental operations and

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maintenance expenses through 2020 of $110 million are within the amount authorized in the settlement agreement and SCE included this amount in rates on October 1, 2020.

Wildfire Mitigation Plans

SCE's WMPs describe strategies, programs and activities that are in place, being implemented or are under development by SCE, including associated cost estimates, to reduce the risk of SCE equipment contributing to the ignition of wildfires.

SCE filed its 2020 – 2022 WMP and its 2021 update to its 2020 – 2022 WMP with the CPUC in February 2020 and February 2021, respectively. Many, but not all, of the programs and activities described in SCE's 2020 – 2022 WMP and the 2021 update are part of SCE's 2021 GRC requests or GS&RP application. For further information, see "Management Overview—Southern California Wildfires and Mudslides."

SCE recorded $229 million and $307 million of expenses in the WMP memorandum account during 2020 and 2019, respectively. WMP capital expenditures not authorized in the 2018 GRC or contemplated in the GS&RP proceedings were $190 million and $335 million during 2020 and 2019, respectively.

Expenses from 2018 and 2019 will be recovered in accordance with the GRC track 2 settlement. Expenses from 2020 are subject to reasonableness review through track 3 of the 2021 GRC, described below.

Fire Hazard Prevention Memorandum Account

The FHPMA was established to record the costs incurred related to fire hazard prevention in compliance with decisions from the CPUC. SCE has used the FHPMA to track incremental vegetation management activities undertaken to reduce the risk of fires. SCE recorded expenses of $252 million and $167 million during 2020 and 2019, respectively in the FHPMA.

Expenses from 2018 and 2019 will be recovered in accordance with the GRC track 2 settlement. Expenses from 2020 are subject to reasonableness review through track 3 of the 2021 GRC, described below.

2021 General Rate Case Wildfire Mitigation Memorandum Account Balances

SCE's GRC track 2 expenditures predominantly related to enhanced overhead inspections, an expanded vegetation management program and expert consultant contract labor costs supporting SCE's wildfire mitigation activities. The majority of these expenditures were recorded in the WMP memorandum account and the FHPMA described above.

In October 2020, SCE and the Track 2 Parties filed a motion with the CPUC seeking approval of a settlement among the Track 2 Parties regarding all issues in track 2. The settlement, approved by the CPUC on January 14, 2021, deemed all requested capital expenditures of $302 million and $401 million of operations and maintenance expenditures as reasonably incurred. The CPUC approval of the GRC track 2 settlement led to a $41 million adjustment to regulatory deferrals for 2018 – 2019. The revenue requirement under the settlement was $391 million, after adjusting for flow through taxes. Due to the determination that the AB 1054 Excluded Capital Expenditures associated with the GS&RP were reasonably incurred they were eligible for recovery through securitization, and were not part of the settlement revenue requirement. Securitization of the GS&RP capital expenditures subject to the settlement was completed in February 2021. For information on AB 1054 Excluded Capital Expenditures, see "Management Overview—Southern California Wildfires and Mudslides—2019 Wildfire Legislation—Capital Expenditure Requirement" and "Notes to Consolidated Financial Statements— Note 1. Summary of Significant Accounting Policies."

Incremental wildfire mitigation costs from 2020, including the $502 million of GS&RP capital expenditures above settled amounts, are to be reviewed in track 3 of the 2021 GRC proceeding, which will be filed in March 2021. The schedule for SCE's 2021 GRC includes a proposed decision on track 3 in the first quarter of 2022.

Wildfire Expense Memorandum Accounts

SCE tracks insurance premium costs related to wildfire liability insurance policies as well as other wildfire-related costs in its WEMAs. In September 2020, the CPUC approved SCE's WEMA application to recover $478 million in wildfire insurance premium costs to June 30, 2020 incurred in excess of premiums approved in the 2018 GRC and corresponding financing costs. The decision authorized SCE to collect a total revenue requirement of $505 million over a two-year period. SCE included the authorized revenue requirement in rates in October 2020 and the related costs previously deferred in WEMA were transferred to the BRRBA for collection from customers.

In December 2020, SCE filed a second WEMA application with the CPUC to seek recovery of $215 million of costs recorded in WEMA at December 31, 2020. The costs primarily related to incremental wildfire insurance premium expenses and

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associated costs for wildfire liability insurance policies that provide coverage for the last six months of 2020. SCE has requested a final decision in the second WEMA proceeding that would allow these costs to be recovered in rates beginning in 2022.

Catastrophic Emergency Memorandum Accounts - Drought and 2017 Wildfires

In July 2019, SCE filed an application to recover $79 million in incremental operations and maintenance drought costs incurred from 2017 – 2018 and $8 million of wildfire restoration costs associated with 2017 wildfires. A CPUC decision is expected in the summer of 2021. SCE has continued to incur incremental costs associated with California's drought and at December 31, 2020, SCE has recorded $153 million in a CEMA in relation to these events, including amounts subject to the current proceeding.

2020 Emergency Wildfire Restoration

Multiple wildfires occurred during 2020 causing damage within SCE's service territory and in the region of SCE's Big Creek hydroelectric facility. Restoration work is ongoing in relation to these wildfires. As of December 31, 2020, SCE has recorded $202 million of incremental operation and maintenance expenses in a CEMA in relation to these wildfires. At December 31, 2020 SCE has recorded $410 million of capital expenditures in relation to these restoration efforts. SCE expects to request recovery of incremental portions of these amounts through future CPUC proceedings.

Phase I Decision in Disconnections OIR

In June 2020, the CPUC issued a final decision on the first phase of the ongoing proceeding Order Instituting Rulemaking to Consider New Approaches to Disconnections and Reconnections to Improve Energy Access and Contain Costs ("Disconnections OIR"). This decision applies only to SCE's residential customers and requires the creation of an arrearage management program to forgive a portion of certain low income customers' past arrears as long as they remain current on monthly billing, prohibits use of establishment of credit or reestablishment of service deposits, and caps SCE's disconnection rate. SCE's disconnection rate will be capped at 8% in 2020 and will reduce by 1% each year until 2024.

The decision required SCE to establish a two-way balancing account to reflect the actual costs of disconnections in customer rates and to establish a memorandum account to track the costs of implementing the decision.

In November 2020, the CPUC approved SCE's residential uncollectible balancing account ("RUBA") and the residential disconnections implementation cost memorandum account resulting from the OIR to be effective beginning in June 11, 2020. In December 2020 the CPUC approved the arrearage management plan in line with proposals from SCE, PG&E and SDG&E to include costs for forgiven arrearages in the RUBA and collected through annual updates to customer rates.

Energy Efficiency Incentive Mechanism

The CPUC uses an energy efficiency incentive mechanism called the Efficiency Savings and Performance Incentive Mechanism ("ESPI") to promote energy efficiency programs through California's investor owned utilities. The ESPI is comprised of performance and savings rewards and management fees based on actual energy efficiency expenditures and does not contain any provisions for penalties. The ESPI schedule anticipates payments of the incentive rewards occurring between one and two years after the relevant program year.

SCE requested an award of approximately $10 million in incentives for activities in program years 2018 and 2019. The request was approved in February 2021. This will be the last award before the CPUC directed moratorium on energy efficiency incentive award earnings becomes effective for all IOUs starting in 2021, as the CPUC considers reforming the program for the goals of its current energy efficiency policy.

As a component of SCE's energy efficiency programs, from 2017 – 2019, SCE administered the Upstream Lighting Program, part of a statewide program administered by investor-owned utilities that offered discounted energy efficient light bulbs to customers through incentives to lighting manufacturers. The CPUC began investigating the programs administered by the investor-owned utilities based on reports that investor-owned utilities, including SCE, shipped a significant number of bulbs under the program that could not be tracked to customers. Beginning in January 2020, the CPUC has sought comments on remedies related to SCE's implementation of the Upstream Lighting Program from 2017 through 2019 program years. SCE undertook an independent investigation of bulbs shipped to retailers categorized as grocery and discount businesses during the 2017 to 2019 program years and found that there was overstocking of bulbs and program management shortcomings. Incentives paid to manufacturers for bulbs shipped to grocery and discount businesses during the relevant period, including those that were sold to customers, were approximately $91 million.

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In January 2021, the Public Advocates Office and The Utility Reform Network provided comments to the CPUC arguing that SCE imprudently managed the program and requesting a total of $265 million refund to address the findings. For further information, refer to "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Upstream Lightening Program."

2019 FERC Formula Rate Settlement

In September 2020, the FERC approved a settlement of SCE's formula rates for the 2019 Formula Rate case ("2019 Formula Rate Settlement"). The settlement establishes SCE's FERC transmission revenue requirement for the 2019 FERC Settlement Period. SCE is permitted to request a new formula rate after December 31, 2021, the end of the 2019 FERC Settlement Period. The settlement provides for a total ROE of 10.30% inclusive of CAISO and transmission incentive adders. The settlement also provides that SCE's capital structure for purposes of its formula rate will reflect the higher of SCE's actual equity ratio or 47.50%. The transmission revenue requirement and rates that have been billed to customers prior to the implementation of the 2019 Formula Rate Settlement utilized a base ROE of 11.97%. SCE expects to refund the excess amounts billed to customers through the operation of the Formula Rate in 2021 and 2022. SCE had been recognizing revenue based on the expected outcome of this settlement and the impact of recording the settlement was not material.

2021 FERC Formula Rate Annual Update

SCE filed its 2021 annual update with the FERC in November 2020, with the proposed rates effective January 1, 2021. The update reflects an increase in SCE's transmission revenue requirement of $124 million or 12.9% higher than amounts included in 2020 annual rates. The increase is primarily due to growth in rate base and the effect of refunds from the annual FERC Formula Rate true-up mechanism on 2020 rates.

Capital Investment Plan

Major Transmission Projects

A summary of SCE's most significant transmission and substation construction projects during the next three years 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
West of Devers			Construction			$	740		$	662		2021
Mesa Substation			Construction			641			510			2022
Riverside Transmission Reliability			Licensing			584			19			2026
Alberhill System2			Licensing			486			44			—2
Eldorado-Lugo-Mohave Upgrade			Construction			247			124			2022

1     Direct 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."

2    Includes the original estimated project cost for Alberhill. In January 2020, SCE submitted a supplemental analysis to the CPUC which included alternative projects as well as an update to the original project cost. SCE is unable to predict the timing of a final CPUC decision, the corresponding in-service date, and what the final project costs will be for the Alberhill System Project.

West of Devers

The West of Devers Project consists of upgrading and reconfiguring approximately 48 miles of existing 220-kV transmission lines between the Devers, El Casco, Vista and San Bernardino substations, increasing the power transfer capabilities in support of California's renewable portfolio standards goals.

In January 2021, SCE notified the CAISO and Morongo Transmission LLC, of an estimated in-service date of May 15, 2021. SCE expects Morongo Transmission LLC to exercise an option to invest in the project within 30 days of the in-service date, subject to regulatory approvals. SCE expects to receive up to $400 million in the second or third quarter of 2021 as a result of the investment, which will reduce SCE's rate base as reflected in SCE's rate base forecast. For further details see "—Management Overview—Capital Program."

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Mesa Substation

The Mesa Substation Project consists of replacing the existing 220-kV Mesa Substation with a new 500/220-kV substation. The Mesa Substation Project will address reliability concerns by providing additional transmission import capability, allowing greater flexibility in the siting of new generation, and reducing the total amount of new generation required to meet local reliability needs in the Western Los Angeles Basin area. In October 2019, SCE achieved first energization of the new substation. The remaining phases of construction will be put out for competitive bid and SCE expects that costs associated with the project may change as a result of the competitive bidding process. SCE anticipates project completion in the first quarter of 2022.

Riverside Transmission Reliability

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 would 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 transmission lines in the cities of Riverside, Jurupa Valley and Norco and in portions of unincorporated Riverside County. The purpose of the project is to provide RPU and its customers with adequate transmission capacity to serve existing and projected load, to provide for long-term system capacity for load growth, and to provide needed system reliability.

In October 2018, the CPUC issued an environmental report that identified a new route alternative, as the environmentally preferred project and proposed an additional underground section of the proposed 220-kV power line. In March 2020, the alternative project with revised scope and an updated cost of $584 million was approved by CPUC. The scheduled in-service date of the project has been extended from 2024 to 2026.

In June 2020, SCE filed a petition with the FERC seeking authorization to recover SCE's prudently incurred costs if the project is cancelled or abandoned for reasons beyond SCE's control, and inclusion of 100% of the project's network transmission Construction Work In Progress in transmission rate base during the construction period. In September 2020, the FERC issued orders granting SCE's requests. SCE is allowed to seek recovery of 100% of all prudently incurred costs after September 17, 2020 and 50% of prudently incurred costs prior to that date.

Alberhill System

The Alberhill System Project would consist 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 unincorporated and incorporated portions of 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 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. Ongoing capital spending has been deferred as a result of the CPUC request for additional information. In January 2020, SCE submitted a supplemental analysis to the CPUC for the Alberhill System Project including several system alternatives to the proposed project as well as an update to the original project cost. A final decision on the Alberhill System Project is pending based on the supplemental analysis. Given the uncertainty associated with the resolution of the permitting process, potential revisions to the project have not been reflected in total direct expenditures. SCE continues to believe a system solution is needed for the project area but is unable to predict the timing of a final CPUC decision in connection with the Alberhill System Project proceeding.

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. Excluding land costs, which may be recovered through sale to a third party, SCE has incurred approximately $50 million of direct capital expenditures, including direct division overhead costs, as of December 31, 2020, of which approximately $36 million may not be recoverable if the project is cancelled.

Eldorado-Lugo-Mohave Upgrade

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 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

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tower heights to meet ground clearance requirements; and install fiber optics on the transmission lines to provide communications between existing SCE substations. In April 2019, as directed by the CPUC, SCE filed an amended application for a certificate of public convenience and necessity ("CPCN") with the CPUC for project costs totaling $257 million. A subsequent change to the project work scope reduced the project total cost to $247 million, a decrease of $10 million as compared to when the amended application was filed. In August 2020, the CPUC approved the CPCN for the project. Construction for the project began in November 2020 and the project is expected to be operational in June 2022. On January 20, 2021, the Secretary of the Interior issued a suspension order that effectively placed a 60-day hold on any new project construction on federal land. The new order may delay when the project becomes operational.

Grid Development - Wildfire Mitigation

See "—Regulatory Proceedings—Wildfire Related Regulatory Proceedings."

Grid Development - Transportation Electrification Programs

Charge Ready Programs

In January 2016, the CPUC approved SCE's $22 million Charge Ready Pilot, which allowed SCE to install light-duty electric vehicle charging infrastructure, provide rebates to offset the cost of qualified customer-owned charging stations, and implement a supporting marketing, education and outreach campaign. In December 2018, the CPUC approved Charge Ready Bridge, an additional $22 million of bridge funding to continue electrification efforts while the application for Charge Ready 2 was pending. As of December 31, 2020, SCE completed construction at 81 sites to support 1,301 charge ports under Charge Ready Pilot, and 63 sites to support 1,419 charge ports under Charge Ready Bridge.

In August 2020, the CPUC approved SCE's Charge Ready 2 program. The final decision authorized a budget of $436 million ($314 million capital) in 2018 dollars for a four-year program to support approximately 37,800 light-duty electric vehicle charging ports through an infrastructure program, rebates for charging infrastructure in new multi-unit dwelling construction, and marketing, education, and outreach. The program is expected to add approximately $400 million to SCE's rate base by 2026.

Medium- and Heavy-Duty Vehicle Transportation Electrification

In January 2017, SCE filed an application with the CPUC requesting approval of transportation electrification programs to accelerate the adoption of electric transportation, which is critical to California's climate change and GHG reduction objectives. In May 2018, the CPUC issued a final decision approving a five-year program to install charging infrastructure to support the electrification of 8,490 medium- and heavy-duty electric vehicles at 870 sites, which must be fully contracted for by 2024. The final decision includes an approved five-year budget of $356 million ($242 million capital) in nominal dollars. SCE expects to propose additional programs and pilots in the future.

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 has engaged a decommissioning general contractor 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.

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") 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 ISFSI was completed in August 2020. In October 2019, the California Coastal Commission approved SCE's application for the Coastal Development Permit, the principal discretionary permit required to start major decommissioning activities at San Onofre Units 1 and 2. In August 2020, SCE commenced major decommissioning activities at San Onofre in accordance with the terms of the permit. In 2021, SCE will continue major decommissioning activities in accordance with the terms of the permit, subject to any court rulings in a proceeding brought in December 2019 to challenge the California Coastal Commission's issuance of the permit.

In December 2018, SCE updated its decommissioning cost estimate for decommissioning activities to be completed at San Onofre Units 2 and 3 to $3.4 billion (SCE share is $2.5 billion) in 2017 dollars. That decommissioning cost estimate included costs through the expected decommissioning completion date, then estimated to be in 2051 for San Onofre Units 2 and 3. SCE anticipates updating its decommissioning cost estimate for San Onofre Units 2 and 3, including expected

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decommissioning completion dates, in 2021. Decommissioning cost estimates are subject to a number of uncertainties including the cost of disposal of nuclear waste, 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 $2.9 billion as of December 31, 2020. Based upon the resolution of 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, 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 funds may be required. If additional contributions to the nuclear decommissioning trust funds become necessary, SCE will seek recovery of such additional funds through electric rates and any such recovery will be subject to a reasonableness review by the CPUC. Cost increases resulting from contractual disputes or significant permitting delays, among other things, could cause SCE to materially overrun the decommissioning cost estimate and could materially impact the sufficiency of trust funds.

SCE's share of the San Onofre decommissioning costs recorded during 2020 were $223 million. In December 2020, the CPUC approved disbursements from SCE's nuclear decommissioning trusts to cover forecasted 2021 decommissioning costs, of which SCE's share is $331 million. The CPUC conducts a reasonableness review of each year's recorded costs.

SCE Dividends

CPUC holding company rules require that SCE's dividend policy be established by SCE's 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.

Effective January 1, 2020, the common equity component of SCE's CPUC authorized capital structure was increased from 48% to 52% on a weighted average basis over the January 1, 2020 to December 31, 2022 compliance period. For further information, see "Business—SCE—Overview of Ratemaking Process." Under AB 1054, the impact of SCE's contributions to the Wildfire Insurance Fund are excluded from the measurement of SCE's CPUC-jurisdictional authorized capital structure. For further information, see "Management Overview—Southern California Wildfires and Mudslides."

In May 2020, the CPUC issued a decision on SCE's application to the CPUC for 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 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. The temporary exclusion will lapse on May 7, 2022 or when a determination regarding cost recovery for the 2017/2018 Wildfire/Mudslide Events is made, whichever comes earlier. If the CPUC has not made a determination regarding cost recovery by May 7, 2022, SCE is permitted to file another application for a waiver of compliance with its equity ratio requirement. In the interim, 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. For further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

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 December 31, 2022.

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

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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, SCE's Board of Directors evaluates available information, including when applicable, information pertaining to the 2017/2018 Wildfire/Mudslide Events, to ensure that the California law requirements for the declarations are met. On February 25, 2021, SCE declared a dividend to Edison International of $325 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, its ability to access the capital markets, and generate operating cash flows and earnings. If SCE incurs significant costs related to catastrophic wildfires, including the 2017/2018 Wildfire/Mudslide Events, 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.

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, 2020 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, 2020 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 energy procurement 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. 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 the downgrade occurs.

(in millions)
Collateral posted as of December 31, 20201						$	177
Incremental collateral requirements for purchased power and fuel contracts resulting from a potential downgrade of SCE's credit rating to below investment grade2						31
Incremental collateral requirements for purchased power and fuel contracts resulting from adverse market price movement3						19
Posted and potential collateral requirements						$	227

1    Net collateral provided to counterparties and other brokers consisted of $160 million in letters of credit and surety bonds, $4 million of cash collateral which was offset against net derivative liabilities on the consolidated balance sheets, and $13 million of cash collateral which was reflected in "Other current assets" on the consolidated balance sheets.

2    Represents collateral requirements for accounts payable and market-to market valuation at the end of period. Requirement varies throughout the period and is generally lower at the end of the month.

3    Incremental collateral requirements were based on potential changes in SCE's forward positions as of December 31, 2020 due to adverse market price movements over the remaining lives of the existing power contracts using a 95% confidence level.

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Regulatory Balancing and Memorandum Accounts

SCE's cash flows are affected by regulatory balancing and memorandum accounts overcollections or undercollections. Overcollections and undercollections represent differences between cash collected in current rates for specified forecasted costs and the costs actually incurred. 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. Undercollections or overcollections in these balancing and memorandum accounts impact cash flows and can change rapidly. Undercollections and overcollections generally accrue interest based on a three-month commercial paper rate published by the Federal Reserve.

As of December 31, 2020, SCE had net undercollections of $1.4 billion for regulatory balancing and memorandum accounts, primarily consisting of undercollections related to wildfire mitigation and restoration costs, BRRBA, and COVID-19 related costs, offset by overcollections from public purpose-related programs. Overcollections from public purpose-related programs may decrease as costs are incurred to fund programs established by the CPUC. Undercollections related to BRRBA are expected to decrease as reclassifications of WEMA related undercollections and GS&RP spending are included in customer rates in 2021 and beyond. For further information see "—Historical Cash Flows—SCE." SCE is currently incurring wildfire-related spending at levels significantly exceeding amounts authorized in the 2018 GRC and has recognized regulatory assets for certain of these costs. In July 2020, the CPUC approved establishment of the COVID-19 Pandemic Protection Memorandum Account ("CPPMA"), to track incremental consumer protection costs for residential and small commercial customers. A CEMA is used to track other incremental COVID-19 costs, including costs of sequestering employees at essential work locations. Total spending on COVID-19 costs are expected to continue at higher levels in 2021. See "Notes to Consolidated Financial Statements—Note 11. Regulatory Assets and Liabilities" for further information.

Edison International Parent and Other

In the next 12 months, Edison International expects to fund its net cash requirements through cash on hand, dividends from SCE, and capital market and bank financings. Edison International may finance its ongoing cash requirements, including common stock 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.

Edison International's costs of accessing capital markets has increased due to the risks associated with wildfires in California. Wildfire activity and the COVID-19 pandemic may cause narrower access to, or further increased costs of accessing, bank and capital markets. For further details, see "Management Overview—COVID-19."

At December 31, 2020, Edison International Parent had cash on hand of $32 million and $1.4 billion available to borrow on its $1.5 billion revolving credit facility. The credit facility is available for borrowing needs until May 2024, and may be extended for one additional year with the lenders' approval. Under certain circumstances, the aggregate maximum principal amount under the credit facility may be increased up to $2.0 billion, provided additional lender commitments are obtained.

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, Edison International's Board of Directors evaluates available information, including when applicable, information pertaining to the 2017/2018 Wildfire/Mudslide 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 "—SCE—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 Parent expects to make further capital contributions to SCE in 2021 to increase the common equity component of SCE's capital structure, after CPUC allowed exclusions, to 52% on a weighted average basis over the Capital Structure Compliance Period. For further information, see "—SCE—SCE Dividends."

SCE expects to issue additional debt to finance payments for future resolutions of claims related to the 2017/2018 Wildfire/Mudslide Events that exceed insurance. To enable SCE to issue the necessary debt and to allow Edison International and SCE to maintain investment grade credit ratings, Edison International anticipates issuing securities with up to $1.0 billion of equity content to invest in SCE, during 2021.

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, 2020, Edison International consolidated debt to total capitalization ratio was 0.59 to 1.

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At December 31, 2020, Edison International Parent was in compliance with all financial covenants that affect access to capital.

Edison International Parent's long-term issuer credit ratings are at investment grade levels. However, during the third quarter of 2020, the S&P rating outlooks for all three investor-owned utilities in California were revised to negative due to unprecedented wildfire activity throughout California in August and September of 2020. Edison International Parent's ratings outlook from Moody's and Fitch has remained stable despite 2020 wildfire activity due to the reduced financial risk that wildfires pose to SCE following enactment of AB 1054. For further information, see "Management Overview—Southern California Wildfires and Mudslides."

The following table summarizes Edison International Parent's current long-term issuer credit ratings and outlook from the major credit rating agencies:

Moody's

Fitch

S&P

Long-term Issuer Credit Rating

Baa3

BBB-

BBB

Outlook

Stable

Stable

Negative

Edison International Parent's credit ratings may be further 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 depleted by claims from catastrophic wildfires. The broad economic impacts of the COVID-19 pandemic may also affect Edison International's credit rating. For further information see "Management Overview—COVID-19" and "Risk Factors." 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.

Net Operating Loss and Tax Credit Carryforwards

Edison International has approximately $1.8 billion of tax effected net operating loss and tax credit carryforwards at December 31, 2020 (after offsetting $270 million of unrecognized tax benefits and $218 million of Capistrano Wind net operating loss and tax credit carryforwards), 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. Edison International expects to utilize its net operating loss and tax credit carryforwards through 2028.

Historical Cash Flows

SCE

(in millions)			2020						2019						2018
Net cash provided by (used in) operating activities			$	1,427					$	(91)					$	3,191
Net cash provided by financing activities			3,699						4,771						616
Net cash used in investing activities			(5,094)						(4,678)						(4,300)
Net increase (decrease) in cash, cash equivalents, and restricted cash			$	32					$	2					$	(493)

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Net Cash Provided by (Used in) Operating Activities

The following table summarizes major categories of net cash provided by (used in) operating activities as provided in more detail in SCE's consolidated statements of cash flows for 2020, 2019 and 2018:

			Years ended December 31,												Change in cash flows
(in millions)			2020			2019			2018						2020/2019			2019/2018
Net income (loss)			$	942		$	1,530		$	(189)
Non-cash items1			1,840			1,782			1,291
Subtotal			2,782			3,312			1,102						(530)			2,210
Contributions to Wildfire Insurance Fund			(95)			(2,457)			—						2,362			(2,457)
Changes in cash flow resulting from working capital2			(136)			298			(313)						(434)			611
Regulatory assets and liabilities, net			(1,799)			(1,278)			(92)						(521)			(1,186)
Other noncurrent assets and liabilities, net3			675			34			2,494						641			(2,460)
Net cash provided by (used in) operating activities			$	1,427		$	(91)		$	3,191					$	1,518		$	(3,282)

1    Non-cash items include depreciation and amortization, allowance for equity during construction, impairment and other, Wildfire Insurance Fund amortization expense, deferred income taxes and other.

2    Changes in working capital items include receivables, inventory, amortization of prepaid expenses, accounts payable, tax receivables and payables, and other current assets and liabilities.

3    Includes changes in liabilities for wildfire-related claims and wildfire-related insurance receivables. Also includes nuclear decommissioning trusts. See "Nuclear Decommissioning Activities" below for further information.

Net cash provided by (used in) operating activities was impacted by the following:

Net income and non-cash items decreased in 2020 by $530 million from 2019 primarily due to recognizing a net $1.2 billion charge ($874 million after-tax) related to wildfire-related claims in September 2020, partially offset by higher CPUC-related revenue due to the escalation mechanism as set forth in the 2018 GRC decision.

Net cash used in operating activities was also impacted by cash outflow of $95 million and $2.5 billion related to SCE's contributions to the Wildfire Insurance Fund in 2020 and 2019, respectively. See "Notes to Consolidated Financial Statements—Note 12. Commitment and Contingencies" for further information.

Net cash (outflow) inflow for working capital was $(136) million and $298 million in 2020 and 2019, respectively. Net cash outflow for working capital increased from 2019 to 2020 primarily due to increases in receivables from customers and accrued unbilled revenue of $(357) million in 2020 and $(73) million in 2019, respectively, partially offset by net tax refunds of $50 million and $164 million in 2020 and 2019, respectively. Net cash for working capital in both periods was impacted by insurance premium payments of $(496) million and $(471) million in 2020 and 2019, respectively, primarily for wildfire-related coverage, partially offset by increases in payables of $255 million in 2020 and $237 million in 2019.

Net cash used in regulatory assets and liabilities, including changes in net under collections of balancing accounts, was $1,799 million and $1,278 million in 2020 and 2019, respectively. SCE has a number of balancing accounts, which impact cash flows based on differences between timing of collection of amounts through rates and accrual expenditures. Cash flows were primarily impacted by the following:

2020

•Net undercollections of BRRBA were $622 million at December 31, 2020, compared to net overcollections of $328 million at December 31, 2019. Net undercollections increased by $950 million primarily due to refunds of prior overcollections (including incremental tax benefits and overcollections of distribution revenue that are being refunded over an 18-month period, starting in July 2019, as part of SCE's 2018 GRC decision), reclassification of approximately $500 million in undercollections from WEMA to be collected over a two-year period, starting October 2020, and the CPUC approval of $140 million GS&RP spending to be collected over a one-year period, starting October 2020, partially offset by current year overcollections due to higher distribution revenue primarily driven by higher residential usage.

•Undercollections of $356 million related to wildfire-related expenses that are probable of future recovery from customers, including wildfire risk mitigation costs and insurance premiums, partially offset by an approximately

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$500 million reclassification to BRRBA as discussed above. See "Notes to Consolidated Financial Statements—Note 11. Regulatory Assets and Liabilities" for further information.

•Undercollections of $241 million related to service restoration and damage repair costs that were tracked in CEMA accounts, primarily due to wildfire events incurred in 2020 and drought restoration costs. See "Notes to Consolidated Financial Statements—Note 11. Regulatory Assets and Liabilities" for further information.

•Net undercollections of FERC balancing accounts were $12 million at December 31, 2020, compared to net overcollections of $127 million at December 31, 2019. Net overcollections of FERC balancing accounts decreased by $139 million primarily due to a refund of prior year overcollections, expected recoveries from FERC customers related to 2017/2018 Wildfire/Mudslide Events and higher expenses related to wildfire mitigation and vegetation management, partially offset by overcollections due to current year billing at a higher ROE than approved in the 2019 Formula Rate Settlement.

•Net undercollections for ERRA, PABA and the New System Generation Balancing Account decreased by $201 million primarily due to recovery of prior ERRA and PABA undercollections, partially offset by undercollections in 2020 due to higher than forecasted power purchase price due to warmer than expected weather in the second half of the year.

•Undercollections of $176 million related to incremental costs associated with COVID-19, primarily related to customer uncollectibles, sequestering certain SCE employees and coordination of SCE's response to the emergency. See "Notes to Consolidated Financial Statements—Note 11. Regulatory Assets and Liabilities" for further information.

2019

•BRRBA overcollections decreased by $300 million primarily due to refunds of prior overcollections (including incremental tax benefits) and current year undercollection due to rate changes delayed beyond January 1, 2019, offset by additional overcollection of distribution revenue to be refunded to customers over an 18-month period, starting in July 2019, as part of SCE's 2018 GRC final decision.

•PABA was established in May 2019 to determine and pro-ratably recover from responsible bundled service and departing load customers the "above-market" costs of all generation resources that are eligible for cost recovery. Net undercollections for ERRA, PABA and the New System Generation Balancing Account decreased by $142 million primarily due to recovery of prior ERRA undercollections and overcollections of generation revenue occurring in 2019 and 2018 that are being refunded over an 18-month period, starting in July 2019, as part of SCE's 2018 GRC final decision. The cash inflow was partially offset by lower sales than forecasted in rates, higher than forecasted energy prices experienced in 2019, charges from CPUC-authorized contract terminations and refunds of prior overcollections from the New System Generation Balancing Account.

•Lower cash due to elimination of approximately $360 million in a regulatory liability that was established in 2018 to record adjustments associated with the delay in the 2018 GRC decision. In May 2019, the CPUC approved the final decision in SCE's 2018 GRC, resulting in 2019 and 2018 overcollections being refunded to customers through BRRBA and PABA, as discussed above.

•Additional undercollections of $596 million related to wildfire-related expenses that are probable of future recovery from customers, including wildfire risk mitigation costs, insurance premiums and service restoration and damage repair costs.

•Higher cash due to $115 million of overcollections related to the timing of GHG auction revenue, low carbon fuel standard credit sales, and the related refunds and rebates to eligible customers.

•Additional cash outflow due to refund of prior year overcollection of recovery of certain employee benefit related costs and reversal of the Tax Accounting Memorandum Account overcollection as a result of adoption of the 2018 GRC final decision.

Cash flows provided by other noncurrent assets and liabilities were primarily related to an increase of $1.3 billion and $232 million in liabilities for the 2017/2018 Wildfire/Mudslide Events related claims in 2020 and 2019, respectively. Also impacted by payments of TKM Subrogation Settlement and individual settlement of $1.5 billion in 2020, and the Local Public Entity Settlements payment of $360 million in 2019, each offset by the subsequent insurance recovery of $1.0 billion and $290 million in 2020 and 2019, respectively.

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Cash flows provided by other noncurrent assets and liabilities also includes net earnings from nuclear decommissioning trust investments ($25 million and $67 million in 2020 and 2019, respectively) and SCE's payments of decommissioning costs ($223 million and $172 million in 2020 and 2019, respectively). See "Nuclear Decommissioning Activities" below for further discussion.

Net Cash Provided by Financing Activities

The following table summarizes cash provided by financing activities for 2020, 2019 and 2018. Issuances of debt and preference stock and capital contribution from Edison International Parent are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements" and "—Note 14. Equity."

(in millions)			2020						2019						2018
Issuances of first and refunding mortgage bonds, net of (discount) premium and issuance costs			$	2,676					$	2,306					$	2,692
Long-term debt matured or repurchased			(699)						(82)						(639)
Short-term debt borrowed			2,194						750						—
Short-term debt repaid			(326)						(750)						—
Commercial paper and other short-term borrowing (repayment), net			175						(171)						(520)
Capital contributions from Edison International Parent			1,432						3,250						—
Redemptions of preference stock			(308)						—						—
Payments of common stock dividends to Edison International			(1,332)						(400)						(788)
Payments of preferred and preference stock dividends			(118)						(121)						(121)
Other			5						(11)						(8)
Net cash provided by financing activities			$	3,699					$	4,771					$	616

Net Cash Used in Investing Activities

Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Capital expenditures were $5.5 billion, $4.9 billion and $4.5 billion for 2020, 2019 and 2018, respectively, primarily related to transmission and generation investments. SCE had a net redemption of nuclear decommissioning trust investments of $197 million and $106 million in 2020 and 2019, 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:

(in millions)			2020						2019						2018
Net cash used in operating activities: Net earnings from nuclear decommissioning trust investments			$	25					$	67					$	41
SCE's decommissioning costs			(223)						(172)						(140)
Net cash provided by investing activities: Proceeds from sale of investments			5,927						4,389						4,340
Purchases of investments			(5,730)						(4,283)						(4,231)
Net cash impact			$	(1)					$	1					$	10

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 ($223 million and $172 million in 2020 and 2019, respectively) and reimbursements to SCE from the nuclear decommissioning trust ($222 million and $173 million in 2020 and 2019, respectively).

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Edison International Parent and Other

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

(in millions)			2020						2019						2018
Net cash used in operating activities			$	(164)					$	(216)					$	(14)
Net cash provided by (used in) financing activities			28						132						(534)
Net cash provided by investing activities			123						—						61
Net decrease in cash, cash equivalents and restricted cash			$	(13)					$	(84)					$	(487)

Net Cash Used in Operating Activities

Net cash used in operating activities decreased in 2020 by $52 million from 2019 due to:

•Outflows of $164 million and $137 million from operating activities in 2020 and 2019, respectively, due to payments and receipts relating to interest and operating costs.

•An outflow of $79 million in 2019 primarily related to $164 million of intercompany tax-allocation payments offset by $85 million of federal and state income tax refunds.

Net Cash Provided by (Used in) Financing Activities

Net cash provided by (used in) financing activities were as follows:

(in millions)						2020						2019						2018
Dividends paid to Edison International common shareholders						$	(928)					$	(810)					$	(788)
Dividends received from SCE						1,332						400						788
Capital contribution to SCE						(1,432)						(3,250)						—
Issuance of common stock						912						2,391						—
Long-term debt issuance, net of discount and issuance costs						397						1,390						545
Long-term debt repayments						(400)						—						(15)
Commercial paper and other short-term borrowing (repayment), net						129						(1)						(1,091)
Other						18						12						27
Net cash provided by (used in) financing activities						$	28					$	132					$	(534)

Net Cash Provided by Investing Activities

Net cash provided by investing activities included a cash inflow of $132 million from the sale of a lease investment in Vidalia, Louisiana in 2020. See "Notes to Consolidated Financial Statements—Note 13. Leases" for further information.

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Contractual Obligations and Contingencies

Contractual Obligations

As of December 31, 2020, Edison International Parent and Other and SCE's contractual obligations for the years 2021 through 2025 and thereafter are estimated below.

(in millions)			Total						Less than 1 year						1 to 3 years						3 to 5 years						More than 5 years
SCE:
Long-term debt maturities and interest1			$	30,078					$	1,734					$	2,761					$	2,189					$	23,394
Power purchase agreements2			35,488						3,144						6,003						4,585						21,756
Other operating lease obligations3			240						39						58						39						104
Purchase obligations:4
Other contractual obligations			368						46						86						82						154
Total SCE5,6,7			66,174						4,963						8,908						6,895						45,408
Edison International Parent and Other:
Long-term debt maturities and interest1			3,750						126						1,319						1,055						1,250
Other operating lease obligations			4						1						2						1						—
Total Edison International Parent and Other5			3,754						127						1,321						1,056						1,250
Total Edison International6,7			$	69,928					$	5,090					$	10,229					$	7,951					$	46,658

1    For additional details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements." Amount includes interest payments totaling $12.5 billion and $600 million over applicable period of the debt for SCE and Edison International Parent and Other, respectively.

2    Certain power purchase agreements entered into with independent power producers are treated as operating or finance leases. For further discussion, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" and "—Note 13. Leases."

3    At December 31, 2020, SCE's other operating lease payments were primarily related to vehicles, office space and other equipment. For further discussion, see "Notes to Consolidated Financial Statements—Note 13. Leases."

4    For additional details, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies." At December 31, 2020, other commitments were primarily related to maintaining reliability and expanding SCE's transmission and distribution system and nuclear fuel supply contracts.

5    At December 31, 2020, Edison International Parent and Other and SCE had estimated contributions to the pension and PBOP plans. SCE estimated contributions are $40 million, $29 million, $17 million, $9 million and $8 million in 2021, 2022, 2023, 2024 and 2025, respectively, which are excluded from the table above. Edison International Parent and Other estimated contributions are $24 million, $24 million, $22 million, $20 million and $21 million for the same respective periods and are excluded from the table above. 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.

6    At December 31, 2020, Edison International and SCE had a total net liability recorded for uncertain tax positions of $679 million and $320 million, respectively, which is excluded from the table. 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.

7    The contractual obligations table does not include derivative obligations and asset retirement obligations, which are discussed in "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments" and "—Note 1. Summary of Significant Accounting Policies," respectively.

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Contingencies

SCE has contingencies related to wildfire and debris flow events, wildfire insurance, nuclear insurance, spent nuclear fuel and the Upstream Lighting Program, which are discussed in "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies."

Environmental Remediation

For a discussion of SCE's environmental remediation liabilities, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Environmental Remediation."

Off-Balance Sheet Arrangements

SCE has variable interests in power purchase contracts with variable interest entities and a variable interest in unconsolidated Trust II, Trust III, Trust IV, Trust V and Trust VI that issued $400 million (aggregate liquidation preference) of 5.10%, $275 million (aggregate liquidation preference) of 5.75%, $325 million (aggregate liquidation preference) of 5.375%, $300 million (aggregate liquidation preference) of 5.45% and $475 million (aggregate liquidation preference) of 5.00%, trust securities, respectively, to the public. In the third quarter 2020, SCE Trust II redeemed $180 million of its trust securities from the public, from its issued trust securities of $400 million. See "Notes to Consolidated Financial Statements—Note 3. Variable Interest Entities."

Environmental Developments

For a discussion of environmental developments, see "Business—Environmental Considerations."

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 of 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 its 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 2021 through a CPUC cost of capital adjustment mechanism, see "Liquidity and Capital Resources—SCE" in the MD&A 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:

(in millions)			Carrying Value						Fair Value						10% Increase						10% Decrease
Edison International:
December 31, 2020			$	20,337					$	23,824					$	23,132					$	24,557
December 31, 2019			18,343						20,137						19,413						20,913
SCE:
December 31, 2020			17,204						20,365						19,700						21,071
December 31, 2019			15,211						16,892						16,213						17,619

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. 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. SCE expects recovery of its related hedging costs through the ERRA balancing account or CPUC-approved procurement plans, and as a result, exposure to commodity price is not expected to impact earnings but may impact timing of cash flows. As part of this program, SCE enters into energy options, swaps, forward

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arrangements and congestion revenue rights ("CRRs"). The transactions are pre-approved by the CPUC or executed in compliance with CPUC-approved procurement plans.

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 $108 million and $86 million at December 31, 2020 and 2019, 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:

			December 31,
(in millions)			2020			2019
Increase in electricity prices by 10%			$	18		$	25
Decrease in electricity prices by 10%			(18)			(25)
Increase in gas prices by 10%			9			12
Decrease in gas prices by 10%			(9)			(12)

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, 2020, SCE's power and gas trading counterparty credit risk exposure was $109 million, 99% of which is associated with entities that have an investment grade rating of A or higher. SCE assigns a credit rating to counterparties based on the lower of a counterparty's S&P or Moody'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 results of operations or financial position. For more information on Edison International's accounting policies, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."

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 principles allow a cost that would otherwise be charged as an expense by an unregulated

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entity to be capitalized as a regulatory asset if it is probable that such cost is recoverable through future rates; conversely the principles allow 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, even for programs that do not qualify for recognition of "traditional" regulatory assets and liabilities.

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 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 and liabilities are probable of future recovery or settlement. 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, plant investments and/or liabilities would have to be written off against current period earnings. At December 31, 2020, the consolidated balance sheets included regulatory assets of $8.4 billion and regulatory liabilities of $9.2 billion. If different judgments were reached on recovery of costs and timing of income recognition, SCE's earnings may vary from the amounts reported.

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, available information, 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 Southern California Wildfires

As discussed in "Management Overview," wildfires in SCE's territory, including those where SCE's equipment may be alleged to be associated with the fire's ignition, have caused loss of life and substantial damage in recent years. Wildfires in SCE's territory in December 2017 and November 2018 caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers.

Any potential liability of SCE for damages related to wildfires depends on a number of factors, including whether SCE is determined to have 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 liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes.

Management judgment was required to assess whether a loss contingency was probable and reasonably estimable for the 2017/2018 Wildfire/Mudslide Events. Based on SCE's internal review into the facts and circumstances of each of the

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2017/2018 Wildfire/Mudslide Events and consideration of the risks associated with litigation, Edison International and SCE have incurred material losses in connection with the 2017/2018 Wildfire/Mudslide Events. Edison International and SCE accrued charges, before recoveries and taxes, of $1.3 billion, $232 million and $4.7 billion for the 2017/2018 Wildfire/Mudslide Events in the years ended 2020, 2019 and 2018, respectively. Edison International and SCE recorded expected recoveries from insurance of $2.0 billion for 2017/2018 Wildfire/Mudslide Events during 2018. Edison International and SCE also recorded expected recoveries through FERC electric rates of $84 million, $14 million and $135 million in the years 2020, 2019 and 2018, respectively. The net charges to earnings recorded were $874 million, $157 million and $1.8 billion after-tax in 2020, 2019 and 2018 respectively.

The estimated losses for the 2017/2018 Wildfire/Mudslide Events do not include an estimate of any potential fines or penalties that could be levied against SCE in connection with the 2017/2018 Wildfire/Mudslide Events. Edison International and SCE are currently unable to reasonably estimate the magnitude of any such fines or penalties, or the associated timing if they were to be imposed. 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 as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of the 2017/2018 Wildfire/Mudslide Events, the complexities associated with fires that merge, whether inverse condemnation will be held applicable to SCE with respect to damages caused by the Montecito Mudslides, the preliminary nature of the litigation processes, the uncertainty in estimating damages that may be alleged, and the uncertainty as to how these factors impact future settlements.

At December 31, 2019, Edison International and SCE were unable to determine a best estimate of expected losses within a reasonably estimated range and therefore the charges recorded by Edison International and SCE in 2018 and 2019 represented the lower end of the reasonably estimated range of expected losses. In light of the TKM Subrogation Settlement and increased settlement activity with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation, among other things, management established a best estimate of expected potential losses for alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events litigation in the third quarter of 2020.

Recovery of SCE's actual 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 when 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 has sought recovery for uninsured wildfire-related costs is SDG&E's requests for cost recovery related to 2007 wildfire activity, where FERC allowed 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 SDG&E did not meet the CPUC's prudency standard. As a result, while SCE does not agree with the CPUC's decision, it believes that the CPUC's interpretation and application of the prudency standard to SDG&E creates substantial uncertainty regarding how that standard will be applied to an investor-owned utility in future wildfire cost-recovery proceedings for fires ignited prior to July 12, 2019. SCE will continue to evaluate the probability of recovery based on available evidence, including judicial, legislative and regulatory decisions, including any CPUC decisions illustrating the interpretation and/or application of the prudency standard when making determinations regarding recovery of uninsured wildfire-related costs. While the CPUC has not made a determination regarding SCE's prudency relative to any of the 2017/2018 Wildfire/Mudslide Events, SCE is unable to conclude, at this time, that uninsured CPUC-jurisdictional wildfire-related costs are probable of recovery through electric rates. SCE would record a regulatory asset at the time it obtains sufficient information to support a conclusion that recovery is probable. 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 debris flow-related costs and has recorded expected recoveries within the FERC balancing account.

Over the course of the various investigations and litigation processes associated with each of the 2017/2018 Wildfire/Mudslide Events, new facts may emerge as to the cause, extent and magnitude of potential damages. The amount of the expected loss and recorded receivables are subject to change based on new or additional information.

Income Taxes

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 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.

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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 U.S. GAAP earnings and then estimates the impact of future taxable income, reversing temporary differences and available prudent and feasible tax planning strategies.

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, and 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 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 Nuclear Decommissioning Cost Triennial Proceeding ("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 $6.6 billion undiscounted through 2079 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 2017 decommissioning study that was filed as part of the 2018 NDCTP for San Onofre Units 1, 2, and 3, with revisions to the cost estimate in 2018, and a 2019 decommissioning study for Palo Verde, with revisions to the cost estimate in 2020.

•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 0.6% to 7.5% (depending on the cost element) annually.

•Timing. 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, 3 operating licenses currently expire in 2045, 2046 and 2047, respectively. 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 2051.

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•Spent Fuel Dry Storage Costs. Cost estimates are based on an assumption that the U.S. Department of Energy will begin to take spent fuel from the nuclear industry in 2028 and will remove the last spent fuel from the San Onofre and Palo Verde sites by 2049 and 2078, 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 $2.6 billion as of December 31, 2020, based on the 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:

(in millions)			Increase to ARO and Regulatory Asset at December 31, 2020
Uniform increase in escalation rate of 1 percentage point			$	473

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.

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. Additionally, health care cost trend rates are critical assumptions for postretirement health care plans. These critical assumptions are evaluated at least annually. Other assumptions, which require management judgment, such as rate of compensation increases and rates of retirement and turnover, are evaluated periodically and updated to reflect actual experience.

As of December 31, 2020, Edison International's and SCE's pension plans had a $4.5 billion and $4.0 billion benefit obligation, respectively, and total 2020 expense for these plans was $58 million and $54 million, respectively. As of December 31, 2020, the benefit obligation for both Edison International's and SCE's PBOP plans were $2.1 billion, and total 2020 expense for Edison International's plans were $1 million, and no expense for SCE's plan. Annual contributions made to most of SCE's pension plans are currently 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, 2020, this cumulative difference amounted to a regulatory asset of $95 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.

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Edison International and SCE used the following critical assumptions to determine expense for pension and other postretirement benefit for 2020:

(in millions)			Pension Plans			Postretirement Benefits Other than Pensions
Discount rate1			3.11		%	3.32		%
Expected long-term return on plan assets2			6.00		%	4.90		%
Assumed health care cost trend rates3			*			6.50		%

*    Not applicable to pension plans.

1    The 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 Aon- Hewitt AA Only Bond Universe yield curve on the measurement date.

2    To 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 4.9% 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 16.3%, 11.0% and 9.7% for the one-year, five-year and ten-year periods ended December 31, 2020, respectively. Actual time-weighted, annualized returns on the PBOP plan assets were 13.0%, 9.4% and 8.8% over these same periods. Accounting principles provide that differences between expected and actual returns are recognized over the average future service of employees.

3    The health care cost trend rate gradually declines to 5.0% for 2029 and beyond.

As of December 31, 2020, Edison International and SCE had unrecognized pension costs of $107 million and $28 million, respectively, and unrecognized PBOP gains of $670 million and $671 million, respectively. The unrecognized pension costs and PBOP gains primarily consisted of the cumulative impact of the reduced 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 costs or gains, $12 million of SCE's pension costs and $671 million of SCE's PBOP gains are recorded as regulatory assets and regulatory liabilities, respectively, and are expected to be recovered or refunded over the average expected future service of employees.

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:

			Edison International												SCE
(in millions)			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			$	(447)					$	548					$	(404)					$	496
Change to accumulated benefit obligation for PBOP			(289)						346						(288)						345

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 $36 million and $34 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 $24 million.

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Contributions to the Wildfire Insurance Fund

Nature of Estimates Required. At December 31, 2020, Edison International and SCE have a $2.4 billion long-term asset and a $323 million current asset reflected as "Wildfire Insurance Fund contributions" in the consolidated balance sheets for the initial $2.4 billion contribution made during the third quarter of 2019 and the present value of annual contributions SCE committed to make to the Wildfire Insurance Fund, reduced by amortization. At December 31, 2020, a long-term liability of $703 million has been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contribution amounts. Contributions were discounted to the present value at the date SCE committed to participate in the Wildfire Insurance Fund using US treasury interest rates.

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 estimated that the Wildfire Insurance Fund will provide insurance coverage for a period of 10 years. 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, 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. In estimating the period of coverage, Edison International and SCE used Monte Carlo simulations based on five years (2014 – 2018) of historical data from wildfires caused by electrical utility equipment to estimate expected loss. 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 12-year period of historical data, with average annual statewide gross claims of $5.0 billion, compared to $11.7 billion for the five year historical data, would increase the period of coverage to 20 years.

Based on information available in the first quarter of 2021 regarding catastrophic wildfires during 2019 and 2020, SCE reassessed its estimate of the life of the Wildfire Insurance Fund. Using 7 years of historical data (2014 – 2020) of wildfires caused by electrical utility equipment to create Monte Carlo simulations of expected loss, resulted in the expected life of the Wildfire Insurance Fund increasing from 10 years to 15 years from the date SCE committed to participate in the Wildfire Insurance Fund.

Effect if Different Assumptions Used. Changes in the estimated life of the insurance 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."

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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 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, SCE and Edison International 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 "Liquidity and Capital Resources—SCE—SCE Dividends" in the MD&A. 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.

Edison International's business activities are concentrated in one industry and in one region.

Edison International business activities are concentrated in the electric utility industry. Its principal subsidiary, SCE, serves customers only in southern and central California. As a result, Edison International'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 "Management Overview—Southern California Wildfires and Mudslides" in the MD&A.

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 be required to incur expenses before the relevant regulatory agency approves the recovery of such costs. For example, SCE has, and continues to, incur costs to strengthen its wildfire mitigation and prevention efforts before it is clear whether such costs will be recoverable from customers. Also, the CPUC may deny recovery of uninsured wildfire-related costs incurred by SCE if the CPUC determines that SCE was not prudent. 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 from the relevant regulatory agencies.

SCE's 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 current CPUC-authorized cost of capital, which currently consists of cost of long-term debt of 4.74%, cost of preferred equity of 5.70% and a ROE of 10.3%, is subject to potential adjustment should interest rates move substantially in years between cost of capital proceedings. For further

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information on the cost of capital mechanism see "Liquidity and Capital Resources—SCE" in the MD&A and "Business—SCE—Overview of Ratemaking Process."

SCE's capital investment plan, increasing procurement of renewable power and energy storage, increasing environmental regulations, currently leveling demand, and the cumulative impact of other public policy requirements, collectively place continuing upward pressure on customer rates. If SCE is unable to obtain a sufficient rate increase or modify its rate design to recover its costs (including an adequate return on capital) in rates in a timely manner, its financial condition and results of operations could be materially affected. For further information on SCE's rate requests, see "Management Overview—2021 GRC," "Management Overview—Wildfire Mitigation, Wildfire Insurance and Restoration Expenses" and "Liquidity and Capital Resources—SCE—Regulatory Proceedings" in the MD&A.

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. The NRC regulates the decommissioning of San Onofre in addition to the local and state agencies that require permits. The construction, planning, and siting of SCE's power plants 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 abide by their respective 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.

To the extent the Wildfire Insurance Fund and other provisions of AB 1054 do not 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, not achieving a more comprehensive solution 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 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 "Management Overview—Southern California Wildfires and Mudslides" and "Management Overview—Wildfire Mitigation, Wildfire Insurance Expenses and Restoration Expenses" 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 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 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.

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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 increased urban development in 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 territory 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. The rationale generally stated by these courts for applying this theory to investor-owned utilities is that property losses resulting from a public improvement, such as the distribution of electricity, can be spread across the larger community that benefited from such improvement. However, in November 2017, the CPUC issued a decision denying an investor-owned utility's request to include in its rates uninsured wildfire-related costs arising from several 2007 fires, finding that the investor-owned utility did not prudently manage and operate its facilities prior to or at the outset of the 2007 wildfires. 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 found liable for damages related to catastrophic wildfires, including the 2017/2018 Wildfire/Mudslide Events, and is unable to, or believes that it will be unable to, recover those damages 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 "Liquidity and Capital Resources—SCE—SCE Dividends" in the MD&A. See "Management Overview—Southern California Wildfires and Mudslides" in the MD&A.

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, further 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 arising from its ordinary operations may not be sufficient.

Edison International has experienced increased costs and difficulties in obtaining insurance coverage for wildfires that could arise in connection with SCE's ordinary operations. Edison International, SCE and its contractors may experience coverage reductions and/or increased wildfire insurance costs in future years. No assurance can be given that losses will not exceed the limits of SCE's or its contractors' insurance coverage. SCE may not be able to recover uninsured losses and increases in the cost of insurance in electric rates. Losses which are not fully insured or cannot be recovered through the Wildfire Insurance Fund or electric 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 territory 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 sourcing, engaging, training and retaining contract workers 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, On a risk-informed basis, SCE is making efforts to reduce the frequency and impacts of PSPS in 2021 as compared to 2020, assuming that weather patterns in 2021 are similar to those experienced in 2020. SCE may be subject to mandated changes to, or restrictions on, its operational PSPS practices, regulatory fines and penalties, claims for damages and reputational harm if

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SCE does not execute PSPS in compliance with applicable rules and regulations or if it is determined that SCE has placed excessive reliance on PSPS.

SCE establishes the criteria under which it implements PSPS in its territory. 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 territory during high wind events.

For more information on AB 1054, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides—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.

For more information on AB 1054, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides—Recovery of Wildfire-Related Costs—2019 Wildfire Legislation."

There are inherent risks associated with owning and decommissioning nuclear power generating 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 on current decommissioning cost estimates, SCE believes that further contributions to the nuclear decommissioning trusts' assets may be required to pay the costs of decommissioning. 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 or significant 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 $13.8 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 $450 million per site. 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. 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 $450 million at a nuclear reactor which is participating in the program. If this public liability limit of $13.8 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 anticipated new customer service system is subject to implementation and cost-recovery risks that could materially affect SCE's business and financial condition.

SCE is currently testing a new customer service system that it anticipates implementing in the second quarter of 2021. If the customer service system does not function as intended upon implementation, SCE could experience, among other things,

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delayed or inaccurate customer bills that lead to over- or under- collections and other customer service concerns or degradation. Further, the process of implementing new technologies like the new customer service system represents opportunity for cybersecurity attacks on SCE's information systems, which could lead to sensitive confidential personal and other data being compromised. Customer service degradation or the compromise of sensitive confidential personal and other data could result in violations of applicable privacy and other laws, material financial loss to SCE or to its customers, customer dissatisfaction, loss of confidence in SCE's security measures, and significant litigation and/or regulatory exposure, all of which could materially affect SCE's financial condition and results of operations and materially damage the business reputation of Edison International and SCE.

The expected cost of the new customer service system is significantly higher than SCE had originally projected. If the CPUC determines that any costs incurred by SCE to design, build, test and implement the customer service system were not reasonably or prudently incurred, SCE will not be able to recover such costs through electric rates.

Climate change exacerbated weather-related incidents and other natural disasters could 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 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.

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 debris flows occurring as a result of rain may be heightened. For example, the 2017/2018 Wildfire/Mudslide Events resulted in, among other things, loss of life, property damage and loss of service. For more information on the impact of the 2017/2018 Wildfire/Mudslide Events on SCE and Edison International, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

Extreme heat events can lead to prolonged widespread outages due to, among other things, rotating outages or equipment failure. Extreme weather events can also lead to use of PSPS. Earthquakes and weather-related events, such as debris flows and melting of significantly higher than normal snow pack, can cause over-topping or failure at an SCE dam resulting in a rapid release of water that could cause, among other things, 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.

The generation, transmission and distribution of electricity are hazardous and involve inherent risks of damage to private property and injury to employees and the general public.

Electricity poses hazards for employees 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 generating facilities include public and employee 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. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. 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.

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SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage the risks inherent in operating and maintaining its facilities.

SCE's infrastructure is aging and could pose a risk to system reliability. In addition, as described above, wildfires in SCE's service territory can cause significant public safety issues, property damage and operational issues. In order to mitigate these risks, SCE is engaged in a significant and ongoing infrastructure investment program. This substantial investment program elevates operational risks and the need for superior execution in SCE's activities. 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 operating and maintaining its facilities, the operation of which can be hazardous. SCE's inherent operating risks include such matters as the risks of human performance, workforce capabilities, 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, and interruptions in necessary supplies.

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 distribution system may be exacerbated due to aging infrastructure. 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 rate payers, 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 capital markets. If SCE were unable to access the capital markets or the cost of financing were to substantially increase, its liquidity and operations could be materially affected.

SCE regularly accesses the capital markets to finance its activities and is expected to do so by its regulators as part of its obligation to serve as a regulated utility. SCE's needs for capital for its ongoing infrastructure investment program are substantial. 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, 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

SCE's inability to effectively and timely respond to the changes that the electricity industry is undergoing, as a result of increased competition, technological advances, and changes to the regulatory environment, could materially impact SCE's business model, financial condition and results of operations.

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 infrastructures. If SCE is unable to effectively 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

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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 utility rates for those customers who do not own their generation. If regulations aren't changed such that customers pay their share of transmission and distribution charges and non-bypassable charges or the demand for electricity reduces so significantly that SCE is no longer effectively able to recover such charges 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."

Cybersecurity and Physical Security Risks

SCE's systems and network infrastructure are targets for physical and cyber attacks, intrusions or other catastrophic events that could result in their failure or reduced functionality.

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 exploit potential vulnerabilities in the U.S. national electric grid and other energy infrastructures, and that such attacks and disruptions, both physical and cyber, are highly sophisticated and dynamic. In 2020, several U.S. Government agencies have highlighted the increasing risks related to ransomware attacks and cybersecurity risks related to the electric sector, including its supply chains.

SCE's operations require the continuous availability of critical information technology systems, sensitive customer and employee data and network infrastructure and information, all of which are targets for malicious actors. New cyber and physical threats arise as SCE moves from an analog to a digital electric grid. For example, SCE's grid modernization efforts and the move to a network-connected grid increases the number of "threat surfaces" and potential vulnerabilities that an adversary can target.

SCE depends on a wide array of vendors to provide it with services and equipment. Malicious actors may attack vendors to disrupt the services they provide to SCE, or to use those vendors as a cyber conduit to attack SCE. Additionally, the equipment and material provided by SCE's vendors may contain cyber vulnerabilities. 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 electronic data, loss of intellectual property and interruption of business processes. While some of SCE's vendors have experienced cybersecurity incidents, such incidents have not, to SCE’s knowledge, resulted in a material impact to SCE to date.

SCE's systems have experienced, and will continue to experience, cybersecurity incidents involving attacks of malicious codes, unauthorized access attempts, and other illicit activities, but to SCE's knowledge it has not experienced a material cybersecurity or data breach to date. Though SCE actively monitors developments in this area and is involved in various industry groups and government initiatives, no security measures can completely shield its systems and infrastructure from cyber attacks, intrusions or other catastrophic events that could result in their failure or reduced functionality.

If SCE's information technology and operational technology systems' security measures were to be breached, or a critical system failure were to occur without timely recovery, SCE could be unable to fulfill critical business functions, such as delivery of electricity to customers, and/or sensitive confidential personal and other data could be compromised, which could result in violations of applicable privacy and other laws, material financial loss to SCE or to its customers, loss of confidence in SCE's security measures, customer dissatisfaction, and significant litigation and/or regulatory exposure, all of which could materially affect SCE's financial condition and results of operations and materially damage the business reputation of Edison International and SCE. 

RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY

Edison International's and SCE's financial condition and results of operations could be materially impacted by events, like the COVID-19 pandemic, that cause significant disruption to economies, societies or workforces on a regional, statewide, national or global basis.

Edison International and SCE could be materially and adversely impacted by events, such as the widespread outbreak of a communicable disease, that result in, among other things, significant disruption to economies, societies or workforces on a regional, statewide, national or global basis. The global spread of COVID-19, which was declared a pandemic by the World Health Organization in March 2020, has created significant uncertainty, volatility and disruption globally and has impacted the operations of Edison International and SCE. The total impacts of the COVID-19 pandemic on Edison International and

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SCE are still emerging, and the extent to which the pandemic affects Edison International's and SCE's business, operations, cash flows, liquidity and financial results will depend on numerous evolving factors that Edison International and SCE are unable to accurately predict at this time, including, without limitation: the duration and scope of the pandemic; the availability, efficacy and use of vaccinations, governmental, business and individual actions that have been and continue to be taken in response to the pandemic; the impact of the pandemic on economic activity; and the impact of the pandemic on Edison International's and SCE's employees, customers, contractors, insurers and service providers.

Many of the risks and uncertainties identified in this Form 10-K are, and will be, exacerbated by the impacts of the COVID-19 pandemic and the actions being taken by governmental entities, businesses, individuals and others in response to the pandemic. Some examples follow. Similar to other companies in California, a large portion of Edison International's and SCE's workforce, including employees of their contractors, may be unable to perform their job functions effectively due to illness, family illness, quarantine requirements, social-distancing, telework requirements and other impacts of the COVID-19 pandemic. In addition, as a result of actions being taken in response to the pandemic, SCE's supply chains have faced constraints and SCE has faced challenges from local permitting authorities. If a significant portion of SCE's workforce cannot effectively perform their job functions, SCE is unable to procure required materials, SCE does not timely obtain any required permits and/or local authorities prohibit SCE from conducting previously permitted work, SCE will likely be unable to effectively and timely complete planned work and projects, including its WMP and capital projects. Further, SCE may be unable to effectively execute its PSPS program due to, among other things, requests from local and State authorities not to shut off the power during the pandemic, and thereby may increase the risk of SCE equipment being associated with the ignition of wildfires.

In addition, impacts of the COVID-19 pandemic 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 could also face payment delays and/or defaults from insurers and other counterparties. Furthermore, capital markets were impacted by the pandemic in early 2020 and, at the time, this did increase Edison International's and SCE's costs of accessing those markets. 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 as a result of the pandemic, 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 the impacts of the pandemic. SCE may also incur significant incremental costs as a result of actions it is taking in response to the pandemic, including costs being incurred to maintain its operations and assist its employees who are required to telework or are otherwise impacted by the pandemic. SCE could also face delays in important legal and regulatory proceedings. These impacts, among others, could materially and adversely impact Edison International's and SCE's business, operations, cash flows, liquidity and financial results.

For more information on see "Management Overview—COVID-19" in the MD&A.

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

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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, 2020 and 2019, 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, 2020, including the related notes and schedules of condensed financial information of parent as of December 31, 2020 and 2019 and for each of the three years in the period ended December 31, 2020 and valuation and qualifying accounts for each of the three years in the period ended December 31, 2020 appearing under Item 15 (collectively referred to as the "consolidated financial statements"). We also have audited the Company's internal control over financial reporting as of December 31, 2020, 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, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 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, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Change in Accounting Principle

As discussed in Note 1 to the consolidated financial statements, the Company changed the manner in which it accounts for leases in 2019.

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

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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.

Contingent Liability - Southern California Wildfires and Mudslides

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 territory caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers in the Santa Barbara, Ventura, and Los Angeles Counties. Based on information available to management and consideration of the risks associated with litigation, management expects to incur a material loss in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events. The Company is named as a defendant in multiple lawsuits filed related to both the wildfires and mudslides. Final determinations of liability for the 2017/2018 Wildfire/Mudslide Events, including determinations of whether the Company was negligent, would only be made during lengthy and complex litigation processes. Even when investigations are still pending or 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. As of December 31, 2020, management had paid $1.8 billion in settlements and had estimated losses of $4.4 billion, consisting of $2.2 billion subject to settlements executed after December 31, 2020 and $2.2 billion for remaining alleged and potential claims, and assets for remaining expected recoveries from insurance of $708 million and through FERC electric rates of $89 million related to the 2017/2018 Wildfire/Mudslide Events. Each reporting period, management reviews its loss estimates for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide 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. In the third quarter of 2020, Edison International and SCE entered into an agreement (the "TKM Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Thomas Fire, Koenigstein Fire and Montecito Mudslides litigation collective claims arising from the Thomas Fire, Koenigstein Fire or Montecito Mudslides have been resolved for a settlement amount of $1.2 billion. In January 2021, Edison International and SCE entered into an agreement (the "Woolsey Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Woolsey Fire litigation collective claims arising from the Woolsey Fire have been resolved for a settlement amount of $2.2 billion. SCE has also entered into settlements with approximately one thousand individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation. In 2020 SCE entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $300 million to those individual plaintiffs. In light of the TKM Subrogation Settlement and increased settlement activity with individual plaintiffs in the 2017/2018 Wildfire/Mudslide events litigation, management established a best estimate of expected potential losses for alleged and potential claims. As a result, management recorded a charge of $1.3 billion as of December 31, 2020 related to the 2017/2018 Wildfire/Mudslide Events and expected recoveries through FERC electric rates of $84 million. The resulting net pre-tax charge to earnings was $1.2 billion.

The principal considerations for our determination that performing procedures relating to the 2017/2018 Wildfire/Mudslide Events contingent liability is a critical audit matter are the significant judgment by management when determining the probability of a loss being incurred and the best estimate of expected potential loss for these contingencies related to assumptions and subjective factors based on currently available information and assessments, opinions regarding litigation risk, and prior experience with litigating and settling other wildfire cases. This in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's conclusion related to these loss contingencies.

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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 evaluation of loss contingencies associated with wildfires and mudslides. These procedures also included, among others, obtaining and evaluating the letters of audit inquiry with internal and external legal counsel, assessing the reasonableness of management's assessment regarding whether it is reasonably possible or probable and reasonably estimable that a loss has been incurred, evaluating the assumptions and methods used by management in developing the best estimate of expected potential losses, including currently available information and assessments, opinions regarding litigation risk, and prior experience with litigating and settling other wildfire cases, and testing damage claim settlements. When assessing the assumptions related to the best estimate of expected potential losses, the assumptions used were evaluated for reasonableness considering (i) past wildfire litigation history, and (ii) third-party source data.

Recoverability of Regulatory Assets That Are Not Currently Reflected In Rates

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 Federal Energy Regulatory Commission ("FERC"). Management 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. 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 of 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, 2020, $1.6 billion recorded in wildfire and drought restoration accounts, wildfire-related memorandum accounts, and COVID-19 related memorandum accounts represent wildfire, drought restoration and COVID-19 costs that are probable of future recovery from customers.

The principal consideration for our determination that performing procedures relating to the Company's recoverability of regulatory assets that are not currently reflected in rates is a critical audit matter is the significant judgment by management in determining the costs probable of recovery and reported as an asset on the balance sheet. This in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's assessment of the recoverability of regulatory assets not currently reflected in rates.

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 probability of recovering regulatory assets not currently reflected in rates. These procedures also included, among others, obtaining the Company's correspondence with regulators, evaluating management's assessment regarding the probability of recovery of the regulatory assets at the balance sheet date, evaluating the accounting and disclosure implications, and calculating regulatory assets balances based on provisions outlined in the rate orders. This evidence included reference to historical precedence of similar items and accounting treatment utilized by comparable companies under similar regulatory jurisdictions as well as evaluating progress in discussions between management and the regulator.

/s/ PricewaterhouseCoopers LLP

Los Angeles, California

February 25, 2021

We have served as the Company's auditor since 2002.

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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, 2020 and 2019, 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, 2020, including the related notes and schedule of valuation and qualifying accounts for each of the three years in the period ended December 31, 2020 appearing under Item 15 (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, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America.

Change in Accounting Principle

As discussed in Note 1 to the consolidated financial statements, the Company changed the manner in which it accounts for leases in 2019.

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.

Contingent Liability - Southern California Wildfires and Mudslides

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 territory caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers in the Santa Barbara, Ventura, and Los Angeles Counties. Based on information available to management and consideration of the risks associated with litigation, management expects to incur a material loss in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events. The Company is named as a defendant in multiple lawsuits filed related to both the wildfires and mudslides. Final determinations of liability for the

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2017/2018 Wildfire/Mudslide Events, including determinations of whether the Company was negligent, would only be made during lengthy and complex litigation processes. Even when investigations are still pending or 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. As of December 31, 2020, management had paid $1.8 billion in settlements and had estimated losses of $4.4 billion, consisting of $2.2 billion subject to settlements executed after December 31, 2020 and $2.2 billion for remaining alleged and potential claims, and assets for remaining expected recoveries from insurance of $708 million and through FERC electric rates of $89 million related to the 2017/2018 Wildfire/Mudslide Events. Each reporting period, management reviews its loss estimates for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide 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. In the third quarter of 2020, Edison International and SCE entered into an agreement (the "TKM Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Thomas Fire, Koenigstein Fire and Montecito Mudslides litigation collective claims arising from the Thomas Fire, Koenigstein Fire or Montecito Mudslides have been resolved for a settlement amount of $1.2 billion. In January 2021, Edison International and SCE entered into an agreement (the "Woolsey Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Woolsey Fire litigation collective claims arising from the Woolsey fire have been resolved for a settlement amount of $2.2 billion. SCE has also entered into settlements with approximately one thousand individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation. In 2020 SCE entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $300 million to those individual plaintiffs. In light of the TKM Subrogation Settlement and increased settlement activity with individual plaintiffs in the 2017/2018 Wildfire/Mudslide events litigation, management established a best estimate of expected potential losses for alleged and potential claims. As a result, management recorded a charge of $1.3 billion as of December 31, 2020 related to the 2017/2018 Wildfire/Mudslide Events and expected recoveries through FERC electric rates of $84 million. The resulting net pre-tax charge to earnings was $1.2 billion.

The principal considerations for our determination that performing procedures relating to the 2017/2018 Wildfire/Mudslide Events contingent liability is a critical audit matter are the significant judgment by management when determining the probability of a loss being incurred and the best estimate of expected potential loss for these contingencies related to assumptions and subjective factors based on currently available information and assessments, opinions regarding litigation risk, and prior experience with litigating and settling other wildfire cases. This in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's conclusion related to these loss contingencies.

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 evaluation of loss contingencies associated with wildfires and mudslides. These procedures also included, among others, obtaining and evaluating the letters of audit inquiry with internal and external legal counsel, assessing the reasonableness of management's assessment regarding whether it is reasonably possible or probable and reasonably estimable that a loss has been incurred, evaluating the assumptions and methods used by management in developing the best estimate of expected potential losses, including currently available information and assessments, opinions regarding litigation risk, and prior experience with litigating and settling other wildfire cases, and testing damage claim settlements. When assessing the assumptions related to the best estimate of expected potential losses, the assumptions used were evaluated for reasonableness considering (i) past wildfire litigation history, and (ii) third-party source data.

Recoverability of Regulatory Assets That Are Not Currently Reflected In Rates

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 Federal Energy Regulatory Commission ("FERC"). Management 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. 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 of the Company or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for

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ratemaking purposes. As of December 31, 2020 $1.6 billion recorded in wildfire and drought restoration accounts, wildfire-related memorandum accounts, and COVID-19 related memorandum accounts represent wildfire, drought restoration and COVID-19 costs that are probable of future recovery from customers.

The principal consideration for our determination that performing procedures relating to the Company's recoverability of regulatory assets that are not currently reflected in rates is a critical audit matter is the significant judgment by management in determining the costs probable of recovery and reported as an asset on the balance sheet. This in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's assessment of the recoverability of regulatory assets not currently reflected in rates.

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 probability of recovering regulatory assets not currently reflected in rates. These procedures also included, among others, obtaining the Company's correspondence with regulators, evaluating management's assessment regarding the probability of recovery of the regulatory assets at the balance sheet date, evaluating the accounting and disclosure implications, and calculating regulatory assets balances based on provisions outlined in the rate orders. This evidence included reference to historical precedence of similar items and accounting treatment utilized by comparable companies under similar regulatory jurisdictions as well as evaluating progress in discussions between management and the regulator.

/s/ PricewaterhouseCoopers LLP

Los Angeles, California

February 25, 2021

We have served as the Company's auditor since 2002.

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CONSOLIDATED FINANCIAL STATEMENTS

Consolidated Statements of Income			Edison International
			Years ended December 31,
(in millions, except per share amounts)			2020						2019						2018
Total operating revenue			$	13,578					$	12,347					$	12,657
Purchased power and fuel			4,932						4,839						5,406
Operation and maintenance			3,609						3,018						2,797
Wildfire-related claims, net of insurance recoveries			1,328						255						2,669
Wildfire Insurance Fund expense			336						152						—
Depreciation and amortization			1,967						1,730						1,871
Property and other taxes			438						399						395
Impairment and other (income) expense			(116)						184						78
Gain on sale of lease interest and other operating income			(133)						(5)						(7)
Total operating expenses			12,361						10,572						13,209
Operating income (loss)			1,217						1,775						(552)
Interest expense			(902)						(841)						(734)
Other income			251						193						197
Income (loss) from continuing operations before income taxes			566						1,127						(1,089)
Income tax benefit			(305)						(278)						(739)
Income (loss) from continuing operations			871						1,405						(350)
Income from discontinued operations, net of tax			—						—						34
Net income (loss)			871						1,405						(316)
Preferred and preference stock dividend requirements of SCE			132						121						121
Other noncontrolling interests			—						—						(14)
Net income (loss) attributable to Edison International common shareholders			$	739					$	1,284					$	(423)
Amounts attributable to Edison International common shareholders:
Income (loss) from continuing operations, net of tax			$	739					$	1,284					$	(457)
Income from discontinued operations, net of tax			—						—						34
Net income (loss) attributable to Edison International common shareholders			$	739					$	1,284					$	(423)
Basic earnings (loss) per common share attributable to Edison International common shareholders:
Weighted average shares of common stock outstanding			373						340						326
Continuing operations			$	1.98					$	3.78					$	(1.40)
Discontinued operations			—						—						0.10
Total			$	1.98					$	3.78					$	(1.30)
Diluted earnings (loss) per common share attributable to Edison International common shareholders:
Weighted average shares of common stock outstanding, including effect of dilutive securities			374						341						326
Continuing operations			$	1.98					$	3.77					$	(1.40)
Discontinued operations			—						—						0.10
Total			$	1.98					$	3.77					$	(1.30)

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

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Consolidated Statements of Comprehensive Income						Edison International
						Years ended December 31,
(in millions)						2020						2019						2018
Net income (loss)						$	871					$	1,405					$	(316)
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Net loss arising during period plus amortization of net loss included in net income						—						(9)						(3)
Other						—						—						(4)
Other comprehensive loss, net of tax						—						(9)						(7)
Comprehensive income (loss)						871						1,396						(323)
Less: Comprehensive income attributable to noncontrolling interests						132						121						107
Comprehensive income (loss) attributable to Edison International						$	739					$	1,275					$	(430)

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

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Consolidated Balance Sheets						Edison International
						December 31,
(in millions)						2020						2019
ASSETS
Cash and cash equivalents						$	87					$	68
Receivables, less allowances of $188 and $50 for uncollectible accounts at respective dates						1,130						788
Accrued unbilled revenue						521						488
Inventory						405						364
Insurance receivable						708						—
Income tax receivables						68						118
Prepaid expenses						281						214
Regulatory assets						1,314						1,009
Wildfire Insurance Fund contributions						323						323
Other current assets						224						188
Total current assets						5,061						3,560
Nuclear decommissioning trusts						4,833						4,562
Other investments						53						64
Total investments						4,886						4,626
Utility property, plant and equipment, less accumulated depreciation and amortization of $10,681 and $9,958 at respective dates						47,653						44,198
Nonutility property, plant and equipment, less accumulated depreciation of $94 and $86 at respective dates						186						87
Total property, plant and equipment						47,839						44,285
Regulatory assets						7,120						6,088
Wildfire Insurance Fund contributions						2,443						2,767
Operating lease right-of-use assets						1,088						693
Long-term insurance receivables						75						1,715
Other long-term assets						860						648
Total long-term assets						11,586						11,911
Total assets						$	69,372					$	64,382

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

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Consolidated Balance Sheets						Edison International
						December 31,
(in millions, except share amounts)						2020						2019
LIABILITIES AND EQUITY
Short-term debt						$	2,398					$	550
Current portion of long-term debt						1,029						479
Accounts payable						1,980						1,752
Customer deposits						243						302
Regulatory liabilities						569						972
Current portion of operating lease liabilities						215						80
Wildfire-related claims						2,231						—
Other current liabilities						1,612						1,388
Total current liabilities						10,277						5,523
Long-term debt						19,632						17,864
Deferred income taxes and credits						5,368						5,078
Pensions and benefits						563						674
Asset retirement obligations						2,930						3,029
Regulatory liabilities						8,589						8,385
Operating lease liabilities						873						613
Wildfire-related claims						2,281						4,568
Other deferred credits and other long-term liabilities						2,910						3,152
Total deferred credits and other liabilities						23,514						25,499
Total liabilities						53,423						48,886
Commitments and contingencies (Note 12)
Common stock, no par value (800,000,000 shares authorized; 378,907,147 and 361,985,133 shares issued and outstanding at respective dates)						5,962						4,990
Accumulated other comprehensive loss						(69)						(69)
Retained earnings						8,155						8,382
Total Edison International's common shareholders' equity						14,048						13,303
Noncontrolling interests – preferred and preference stock of SCE						1,901						2,193
Total equity						15,949						15,496
Total liabilities and equity						$	69,372					$	64,382

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

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Consolidated Statements of Cash Flows						Edison International
						Years ended December 31,
(in millions)						2020						2019						2018
Cash flows from operating activities:
Net income (loss)						$	871					$	1,405					$	(316)
Less: Income from discontinued operations						—						—						34
Income (loss) from continuing operations						871						1,405						(350)
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization						2,029						1,803						1,940
Allowance for equity during construction						(121)						(101)						(104)
Impairment and other (income) expense						(116)						184						78
Gain on sale of lease interest and other operating income						(133)						(5)						(7)
Deferred income taxes						(296)						(284)						(527)
Wildfire Insurance Fund amortization expense						336						152						—
Other						36						34						42
Nuclear decommissioning trusts						(197)						(106)						(109)
Contributions to Wildfire Insurance Fund						(95)						(2,457)						—
Changes in operating assets and liabilities:
Receivables						(283)						(76)						(39)
Inventory						(43)						(83)						(49)
Accounts payable						87						288						(31)
Tax receivables and payables						113						88						32
Other current assets and liabilities						4						(13)						(79)
Regulatory assets and liabilities, net						(1,799)						(1,278)						(92)
Wildfire-related insurance receivable						932						285						(2,000)
Wildfire-related claims						(56)						(101)						4,669
Other noncurrent assets and liabilities						(6)						(42)						(197)
Net cash provided by (used in) operating activities						1,263						(307)						3,177
Cash flows from financing activities:
Long-term debt issued, plus premium and net of discount and issuance costs of $23, $(4) and $(63) for the respective years						3,073						3,696						3,237
Long-term debt repaid or repurchased						(1,099)						(82)						(654)
Short-term debt borrowed						2,994						1,750						—
Short-term debt repaid						(1,126)						(1,750)						—
Common stock issued						912						2,391						—
Preferred and preference stock redeemed						(308)						—						—
Commercial paper and other short-term borrowing (repayments), net						304						(172)						(1,611)
Dividends and distribution to noncontrolling interests						(118)						(121)						(121)
Dividends paid						(928)						(810)						(788)
Other						23						1						19
Net cash provided by financing activities						3,727						4,903						82
Cash flows from investing activities:
Capital expenditures						(5,484)						(4,877)						(4,509)
Proceeds from sale of nuclear decommissioning trust investments						5,927						4,389						4,340
Purchases of nuclear decommissioning trust investments						(5,730)						(4,283)						(4,231)
Proceeds from sale of San Onofre nuclear fuel						158						11						3
Proceeds from sale of lease investment						132						—						—
Other						26						82						158
Net cash used in investing activities						(4,971)						(4,678)						(4,239)
Net increase (decrease) in cash, cash equivalents and restricted cash						19						(82)						(980)
Cash, cash equivalents and restricted cash at beginning of year						70						152						1,132
Cash, cash equivalents and restricted cash at end of year						$	89					$	70					$	152

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

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Consolidated Statements of Changes in Equity																																	Edison International
			Equity Attributable to Common Shareholders																								Noncontrolling Interests
(in millions, except per share amounts)			Common Stock						Accumulated Other Comprehensive Loss						Retained Earnings						Subtotal						Other						Preferred and Preference Stock						Total Equity
Balance at December 31, 2017			$	2,526					$	(43)					$	9,188					$	11,671					$	2					$	2,193					$	13,866
Net loss (income)			—						—						(423)						(423)						(11)						121						(313)
Other comprehensive loss			—						(2)						—						(2)						—						—						(2)
Cumulative effect of accounting changes			—						(5)						10						5						—						—						5
Contribution from tax equity investor			—						—						—						—						24						—						24
Common stock dividends declared ($2.4275 per share)			—						—						(791)						(791)						—						—						(791)
Dividends to noncontrolling interests ($1.020 - $1.195 per share for preferred stock; $62.500 - $143.750 per share for preference stock)			—						—						—						—						—						(121)						(121)
Stock-based compensation			—						—						(20)						(20)						—						—						(20)
Noncash stock-based compensation			19						—						—						19						—						—						19
Deconsolidation of SoCore Energy			—						—						—						—						(15)						—						(15)
Balance at December 31, 2018			$	2,545					$	(50)					$	7,964					$	10,459					$	—					$	2,193					$	12,652
Net income			—						—						1,284						1,284						—						121						1,405
Other comprehensive loss			—						(9)						—						(9)						—						—						(9)
Cumulative effect of accounting changes			—						(10)						10						—						—						—						—
Common stock issued, net of issuance cost			2,421						—						—						2,421						—						—						2,421
Common stock dividends declared ($2.4750 per share)			—						—						(849)						(849)						—						—						(849)
Dividends to noncontrolling interests ($1.020 - $1.195 per share for preferred stock; $62.500 - $143.750 per share for preference stock)			—						—						—						—						—						(121)						(121)
Stock-based compensation			—						—						(27)						(27)						—						—						(27)
Noncash stock-based compensation			24						—						—						24						—						—						24
Balance at December 31, 2019			$	4,990					$	(69)					$	8,382					$	13,303					$	—					$	2,193					$	15,496
Net income			—						—						739						739						—						132						871
Common stock issued, net of issuance cost (Note 14)			942						—						—						942						—						—						942
Common stock dividends declared ($2.5750 per share)			—						—						(965)						(965)						—						—						(965)
Dividends to noncontrolling interests ($0.757 - $0.886 per share for preferred stock; $62.500 - $143.750 per share for preference stock)			—						—						—						—						—						(117)						(117)
Noncash stock-based compensation and other			30						—						(1)						29						—						1						30
Redemption of preferred and preference stock			—						—						—						—						—						(308)						(308)
Balance at December 31, 2020			$	5,962					$	(69)					$	8,155					$	14,048					$	—					$	1,901					$	15,949

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

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Consolidated Statements of Income			Southern California Edison Company

						Years ended December 31,
(in millions)						2020						2019						2018
Operating revenue						$	13,546					$	12,306					$	12,611
Purchased power and fuel						4,932						4,839						5,406
Operation and maintenance						3,523						2,936						2,702
Wildfire-related claims, net of insurance recoveries						1,328						255						2,669
Wildfire Insurance Fund expense						336						152						—
Depreciation and amortization						1,965						1,728						1,867
Property and other taxes						435						396						392
Impairment and other (income) expense						(150)						159						(12)
Other operating income						(1)						(4)						(7)
Total operating expenses						12,368						10,461						13,017
Operating income (loss)						1,178						1,845						(406)
Interest expense						(768)						(739)						(673)
Other income						255						195						194
Income (loss) before taxes						665						1,301						(885)
Income tax benefit						(277)						(229)						(696)
Net income (loss)						942						1,530						(189)
Less: Preferred and preference stock dividend requirements						132						121						121
Net income (loss) available for common stock						$	810					$	1,409					$	(310)

Consolidated Statements of Comprehensive Income
						Years ended December 31,
(in millions)						2020						2019						2018
Net income (loss)						$	942					$	1,530					$	(189)
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Net loss arising during period plus amortization of net loss included in net income						(2)						(11)						1
Other						—						—						(5)
Other comprehensive loss, net of tax						(2)						(11)						(4)
Comprehensive income (loss)						$	940					$	1,519					$	(193)

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

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Consolidated Balance Sheets			Southern California Edison Company

						December 31,
(in millions)						2020						2019
ASSETS
Cash and cash equivalents						$	55					$	24
Receivables, less allowances of $188 and $49 for uncollectible accounts at respective dates						1,126						777
Accrued unbilled revenue						521						488
Inventory						405						364
Insurance receivable						440						—
Insurance receivable from affiliate						268						—
Income tax receivables						69						148
Prepaid expenses						280						213
Regulatory assets						1,314						1,009
Wildfire Insurance Fund contributions						323						323
Other current assets						216						184
Total current assets						5,017						3,530
Nuclear decommissioning trusts						4,833						4,562
Other investments						37						46
Total investments						4,870						4,608
Utility property, plant and equipment, less accumulated depreciation and amortization of $10,681 and $9,958 at respective dates						47,653						44,198
Nonutility property, plant and equipment, less accumulated depreciation of $86 and $80 at respective dates						180						83
Total property, plant and equipment						47,833						44,281
Regulatory assets						7,120						6,088
Wildfire Insurance Fund contributions						2,443						2,767
Operating lease right-of-use assets						1,085						689
Long-term insurance receivables						75						912
Long-term insurance receivables due from affiliate						—						803
Other long-term assets						843						595
Total long-term assets						11,566						11,854
Total assets						$	69,286					$	64,273

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

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Consolidated Balance Sheets			Southern California Edison Company

						December 31,
(in millions, except share amounts)						2020						2019
LIABILITIES AND EQUITY
Short-term debt						$	2,268					$	550
Current portion of long-term debt						1,029						79
Accounts payable						1,983						1,779
Customer deposits						243						302
Regulatory liabilities						569						972
Current portion of operating lease liabilities						214						79
Wildfire-related claims						2,231						—
Other current liabilities						1,294						1,298
Total current liabilities						9,831						5,059
Long-term debt						16,499						15,132
Deferred income taxes and credits						6,783						6,451
Pensions and benefits						144						237
Asset retirement obligations						2,930						3,029
Regulatory liabilities						8,589						8,385
Operating lease liabilities						871						610
Wildfire-related claims						2,281						4,568
Other deferred credits and other long-term liabilities						2,708						2,975
Total deferred credits and other liabilities						24,306						26,255
Total liabilities						50,636						46,446
Commitments and contingencies (Note 12)
Preferred and preference stock						1,945						2,245
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						5,387						3,939
Accumulated other comprehensive loss						(41)						(39)
Retained earnings						9,191						9,514
Total equity						18,650						17,827
Total liabilities and equity						$	69,286					$	64,273

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

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Consolidated Statements of Cash Flows						Southern California Edison Company
						Years ended December 31,
(in millions)						2020						2019						2018
Cash flows from operating activities:
Net income (loss)						$	942					$	1,530					$	(189)
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization						2,021						1,798						1,931
Allowance for equity during construction						(121)						(101)						(104)
Impairment and other (income) expense						(150)						159						(12)
Deferred income taxes						(263)						(243)						(552)
Wildfire Insurance Fund amortization expense						336						152						—
Other						17						17						28
Nuclear decommissioning trusts						(197)						(106)						(109)
Contributions to Wildfire Insurance Fund						(95)						(2,457)						—
Changes in operating assets and liabilities:
Receivables						(290)						(89)						(45)
Inventory						(43)						(83)						(50)
Accounts payable						63						307						(43)
Tax receivables and payables						141						178						(84)
Other current assets and liabilities						(7)						(15)						(91)
Regulatory assets and liabilities, net						(1,799)						(1,278)						(92)
Wildfire-related insurance receivable						932						285						(2,000)
Wildfire-related claims						(56)						(101)						4,669
Other noncurrent assets and liabilities						(4)						(44)						(66)
Net cash provided by (used in) operating activities						1,427						(91)						3,191
Cash flows from financing activities:
Long-term debt issued, plus premium and net of discount and issuance costs of $26, $6 and $(58) for the respective years						2,676						2,306						2,692
Long-term debt repaid or repurchased						(699)						(82)						(639)
Short-term debt borrowed						2,194						750						—
Short-term debt repaid						(326)						(750)						—
Capital contributions from Edison International Parent						1,432						3,250						—
Preferred and preference stock redeemed						(308)						—						—
Commercial paper and other short-term borrowing (repayment), net						175						(171)						(520)
Dividends paid						(1,450)						(521)						(909)
Other						5						(11)						(8)
Net cash provided by financing activities						3,699						4,771						616
Cash flows from investing activities:
Capital expenditures						(5,480)						(4,876)						(4,491)
Proceeds from sale of nuclear decommissioning trust investments						5,927						4,389						4,340
Purchases of nuclear decommissioning trust investments						(5,730)						(4,283)						(4,231)
Proceeds from sale of San Onofre nuclear fuel						158						11						3
Other						31						81						79
Net cash used in investing activities						(5,094)						(4,678)						(4,300)
Net increase (decrease) in cash, cash equivalents and restricted cash						32						2						(493)
Cash, cash equivalents and restricted cash at beginning of year						24						22						515
Cash, cash equivalents and restricted cash at end of year						$	56					$	24					$	22

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

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Consolidated Statements of Changes in Equity			Southern California Edison Company

(in millions, except per share amounts)			Preferred and Preference Stock						Common Stock						Additional Paid-in Capital						Accumulated Other Comprehensive Loss						Retained Earnings						Total Equity
Balance at December 31, 2017			$	2,245					$	2,168					$	671					$	(19)					$	9,607					$	14,672
Net loss			—						—						—						—						(189)						(189)
Other comprehensive income			—						—						—						1						—						1
Cumulative effect of accounting change			—						—						—						(5)						5						—
Dividends declared on common stock ($1.3245 per share)			—						—						—						—						(576)						(576)
Dividends declared on preferred stock ($1.020 - $1.195 per share) and preference stock ($62.500 - $143.750 per share)			—						—						—						—						(121)						(121)
Stock-based compensation			—						—						—						—						(11)						(11)
Noncash stock-based compensation			—						—						9						—						—						9
Balance at December 31, 2018			$	2,245					$	2,168					$	680					$	(23)					$	8,715					$	13,785
Net income			—						—						—						—						1,530						1,530
Other comprehensive loss			—						—						—						(11)						—						(11)
Cumulative effect of accounting change			—						—						—						(5)						5						—
Capital contribution from Edison International Parent			—						—						3,250						—						—						3,250
Dividends declared on common stock ($1.3797 per share)			—						—						—						—						(600)						(600)
Dividends declared on preferred stock ($1.020 - $1.195 per share) and preference stock ($62.500 - $143.750 per share)			—						—						—						—						(121)						(121)
Stock-based compensation			—						—						(3)						—						(15)						(18)
Noncash stock-based compensation			—						—						12						—						—						12
Balance at December 31, 2019			$	2,245					$	2,168					$	3,939					$	(39)					$	9,514					$	17,827
Net income			—						—						—						—						942						942
Other comprehensive loss			—						—						—						(2)						—						(2)
Capital contribution from Edison International Parent			—						—						1,432						—						—						1,432
Dividends declared on common stock ($2.6030 per share)			—						—						—						—						(1,132)						(1,132)
Dividends declared on preferred stock ($0.757 - $0.886 per share) and preference stock ($62.500 - $143.750 per share)			—						—						—						—						(117)						(117)
Stock-based compensation			—						—						(5)						—						—						(5)
Noncash stock-based compensation and other			—						—						14						—						(1)						13
Redemption of preferred and preference stock			(300)						—						7						—						(15)						(308)
Balance at December 31, 2020			$	1,945					$	2,168					$	5,387					$	(41)					$	9,191					$	18,650

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

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1.    Summary of Significant Accounting Policies

Organization and Basis of Presentation

Edison International is the parent holding company of Southern California Edison Company ("SCE") and Edison Energy Group, Inc. ("Edison Energy Group"). 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 of southern California. Edison Energy Group is a holding company for Edison Energy, LLC ("Edison Energy") which is engaged in the competitive business of providing data-driven energy solutions to commercial, institutional and industrial customers. Edison Energy's business activities are currently not material to report as a separate business segment. 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 wholly owned and 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 and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements.

Edison International's and SCE'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 Federal Energy Regulatory Commission ("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 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 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, even for programs that do not qualify for recognition of "traditional" regulatory assets and liabilities. SCE assesses, at the end of each reporting period, whether regulatory assets are probable of future recovery. See Note 11 for composition of regulatory assets and liabilities.

The preparation of financial statements in conformity with United States generally accepted accounting principles ("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 year amounts have been conformed to the current year's presentation, including the presentation of long-term insurance receivables on the consolidated balance sheets of Edison International and Southern California Edison, previously presented as other long-term assets.

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Cash, Cash Equivalents and Restricted Cash

Cash equivalents include 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:

			Edison International												SCE
			December 31,
(in millions)			2020						2019						2020						2019
Money market funds			$	62					$	31					$	38					$	—

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 as follows:

			Edison International												SCE
			December 31,
(in millions)			2020						2019						2020						2019
Book balances reclassified to accounts payable			$	69					$	75					$	69					$	74

The following table sets forth the cash, cash equivalents and restricted cash included in the consolidated statements of cash flows:

(in millions)						December 31, 2020						December 31, 2019
Edison International:
Cash and cash equivalents						$	87					$	68
Short-term restricted cash1						2						2
Total cash, cash equivalents, and restricted cash						$	89					$	70
SCE:
Cash and cash equivalents						$	55					$	24
Short-term restricted cash1						1						—
Total cash, cash equivalents, and restricted cash						$	56					$	24

1    Reflected in "Other current assets" on Edison International's and SCE's consolidated balance sheets.

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 and 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. At December 31, 2020, this included the estimated impacts of the COVID-19 pandemic.

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

			Year ended December 31, 2020
(in millions)			Customers			All others
Beginning balance			$	35		$	14
Plus: current period provision for uncollectible accounts
Included in operation and maintenance expenses			36			9
Deferred to regulatory assets			120			—
Less: write-offs, net of recoveries			16			10
Ending balance			$	175		$	13

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Inventory

SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at weighted average cost.

Emission Allowances and Energy Credits

SCE is allocated greenhouse gas ("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 had GHG allowances held for use of $78 million and $50 million at December 31, 2020 and 2019, respectively. GHG emission obligations were $64 million and $50 million at December 31, 2020 and 2019, 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 program costs, are recorded in a balancing account to be refunded to eligible customers. SCE's net proceeds from the sale of these LCFS credits were $176 million and $184 million and are classified as "Regulatory liabilities" on the consolidated balance sheets at December 31, 2020 and 2019, respectively.

Property, Plant and Equipment

SCE plant additions, including eligible replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, pension and 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 2018 General Rate Case ("GRC") and weighted average useful lives of SCE's property, plant and equipment, are as follows:

			Estimated Useful Lives			Weighted Average Useful Lives
Generation plant			10 years to 55 years			36 years
Distribution plant			20 years to 65 years			48 years
Transmission plant			45 years to 65 years			54 years
General plant and other			5 years to 60 years			25 years

Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. SCE's depreciation expense was $1.8 billion, $1.7 billion and $1.7 billion for 2020, 2019 and 2018, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.6%, 3.6% and 3.7% for 2020, 2019 and 2018, respectively. The original costs of retired property are charged to accumulated depreciation. See Note 2 for further information.

Nuclear fuel for the Palo Verde Nuclear Generating Station ("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. AFUDC equity 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. AFUDC equity was $121 million, $101 million and $104 million in 2020, 2019 and 2018, respectively, and is reflected in "Other income." AFUDC debt was $53 million, $63 million and $44 million in 2020, 2019 and 2018, respectively and is reflected as a reduction of "Interest expense."

Major Maintenance

Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred.

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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 amount of the disallowance can be made.

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. Edison International and SCE have a $2.4 billion and $2.8 billion long-term asset at December 31, 2020 and December 31, 2019, respectively, and a $323 million current asset reflected as "Wildfire Insurance Fund contributions" in the consolidated balance sheets for the initial $2.4 billion contribution made during the third quarter of 2019 and the present value of annual contributions SCE committed to make to the Wildfire Insurance Fund, reduced by amortization at both December 31, 2020 and December 31, 2019. A long-term liability of $703 million and $785 million have been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contribution amounts, at December 31, 2020 and December 31, 2019, respectively. Contributions were discounted to the present value at the date SCE committed to participate in the Wildfire Insurance Fund using US treasury interest rates.

During 2020 a period of 10 years was used to amortize the asset. All expenses related to the contributions are being reflected in "Operation and maintenance" 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 five years (2014 – 2018) of historical data from wildfires caused by electrical utility equipment to estimate expected losses. The details of the operation of the Wildfire Insurance Fund and estimates related to claims by SCE, Pacific Gas & Electric Company ("PG&E") and San Diego Gas & Electric ("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. Edison International and SCE evaluate all inputs annually, or upon claims being made from the fund for catastrophic wildfires, and the expected life of the insurance fund will be adjusted as required. Based on information available in the first quarter of 2021 regarding catastrophic wildfires during 2019 and 2020, SCE reassessed its estimate of the life of the Wildfire Insurance Fund. Using 7 years of historical data (2014 – 2020) of wildfires caused by electrical utility equipment to create Monte Carlo simulations of expected loss, resulted in the expected life of the Wildfire Insurance Fund increasing from 10 years to 15 years from the date SCE committed to participate in the Wildfire Insurance Fund.

Edison International and SCE will assess the Wildfire Insurance Fund contribution assets for impairment in the event that a participating utility's electrical equipment is found to be the substantial cause of a catastrophic wildfire, based on the ability of SCE to benefit from the coverage provided by the Wildfire Insurance Fund in an amount equal to the recorded assets.

Goodwill

Edison International assesses goodwill through an annual goodwill impairment test, at the reporting unit level as of October 1 of each year. Edison International updates its goodwill impairment test between annual tests if events occur or circumstances change such that it is more likely than not that the fair value of a reporting unit is below its carrying value. In June 2020, the goodwill associated with Edison Energy was fully impaired primarily from the economic impact of COVID-19. During the second quarter of 2020 and in the fourth quarter of 2019 and 2018, Edison International recorded an impairment of its Edison Energy reporting unit goodwill totaling $34 million ($25 million after-tax), $25 million ($18 million after-tax), $19 million ($13 million after-tax), respectively. At December 31, 2020 and December 31, 2019, Edison International had no remaining goodwill and $34 million of goodwill, respectively, all of which is related to its Edison Energy reporting unit.

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Nuclear Decommissioning and Asset Retirement Obligations

The fair value of a liability for an asset retirement obligation ("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:

			December 31,
(in millions)			2020						2019
Beginning balance			$	3,029					$	3,031
Accretion1			160						166
Revisions			(36)						4
Liabilities settled			(223)						(172)
Ending balance			$	2,930					$	3,029

1    An 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 Nuclear Decommissioning Cost Triennial Proceeding ("NDCTP") conducted before the CPUC. Revisions of an ARO are established for updated site-specific decommissioning cost estimates.

The ARO for decommissioning SCE's San Onofre Nuclear Generating Station ("San Onofre") and Palo Verde nuclear power facilities is $2.6 billion as of December 31, 2020. The liability to decommission SCE's nuclear power facilities is based on a 2017 decommissioning study that was filed as part of the 2018 NDCTP for San Onofre Units 1, 2 and 3, and a 2019 decommissioning study for Palo Verde. SCE revised the ARO for Palo Verde in 2020 and for San Onofre Units 1, 2 and 3 in 2018 to reflect updated decommissioning cost estimates.

SCE records an ARO regulatory liability as a result of timing differences between the recognition of costs and the recovery of costs through the ratemaking process. For further information, see Note 11.

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") 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 spent nuclear fuel transfer from San Onofre Units 2 and 3 to dry cask storage in the ISFSI was completed in August 2020. In October 2019, the California Coastal Commission approved SCE's application for the Coastal Development Permit, the principal discretionary permit required to start major decommissioning activities at San Onofre. In August 2020, SCE commenced major decommissioning activities at San Onofre in accordance with the terms of the permit.

Decommissioning costs, which are recovered through customer rates over the term of each nuclear facility's operating license, are recorded as a component of depreciation expense, with a corresponding credit to the ARO regulatory liability. Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. 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.

SCE has collected in rates 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 regulatory liabilities.

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 $6.6 billion through 2079 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 0.6% to 7.5% (depending on the cost element)

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annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 1.3% to 4.1% dependent on asset class. If 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.

Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceeding. 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 on a straight-line basis. 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. SCE had unamortized losses on reacquired debt of $133 million and $142 million at December 31, 2020 and 2019, respectively, reflected as long-term "Regulatory assets" in the consolidated balance sheets. In addition, Edison International and SCE had debt issuance costs related to issuances of long-term debt of $131 million and $117 million at December 31, 2020, respectively, and $121 million and $106 million at December 31, 2019, respectively, reflected as a reduction of "Long-term debt" on the consolidated balance sheets.

Amortization of deferred financing costs charged to interest expense is as follows:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Amortization of deferred financing costs charged to interest expense			$	32					$	30					$	30					$	27					$	26					$	26

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 will be 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. Revenue was previously authorized by the CPUC in triennial GRC proceedings. As described above, SCE also earns revenue, with no return, to recover costs for power procurement 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.

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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 receives revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold to customers and specific customer classes 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 $131 million, $122 million and $133 million for the years ended December 31, 2020, 2019 and 2018, 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 compensate SCE for demand-side management initiatives and provide for incentive awards if SCE achieves certain objectives. These alternative revenue programs allow SCE to recover costs that SCE has been authorized to pass on to customers, including costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs. In general, revenue is recognized for these alternative revenue programs at the time the costs are incurred and, for incentive-based programs, at the time the awards are approved by the CPUC. 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.

Regulatory Proceedings

2018 General Rate Case

In May 2019, the CPUC approved a final decision in SCE's 2018 GRC.

The revenue requirements in the 2018 GRC final decision are retroactive to January 1, 2018. SCE recorded the prior period impact of the 2018 GRC final decision in 2019 including:

•An increase to earnings of $65 million attributable to 2018 from the application of the decision to revenue, depreciation expense and income tax expense. The reduction of revenue of $289 million reflected the lower authorized revenue related to 2018.

•An impairment of utility property, plant and equipment of $170 million ($123 million after-tax) related to disallowed historical capital expenditures, primarily the write-off of specific pole replacements the CPUC determined were performed prematurely.

2021 General Rate Case

In the 2021 GRC, SCE has requested a test year revenue requirement of $7.6 billion, an approximately $1.3 billion increase over the 2020 revenue requirement authorized in the 2018 GRC as updated for post test-year ratemaking changes.

SCE believes that receiving a proposed decision on track 1 of the 2021 GRC in the first quarter of 2021 in line with the CPUC’s schedule for track 1 is unlikely. The CPUC has approved the establishment of a memorandum account making the authorized revenue requirement changes effective January 1, 2021. 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 2020 authorized revenue requirement until a GRC decision is issued.

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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 should consolidate the VIE. None of SCE's PPAs resulted in consolidation of a VIE at December 31, 2020 and 2019. 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, including agreements that are classified as operating and finance leases for accounting purposes.

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. These PPAs may be eligible for an election to designate as a normal purchase and sale, which is accounted for on an accrual basis as an executory contract. See Note 6 for further information on derivative instruments.

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

On January 1, 2019, Edison International and SCE adopted accounting standards updates that require lessees to recognize a lease on the balance sheet as a right-of-use ("ROU") asset and related lease liability and classify the lease as either operating or finance. 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 identified asset and has the right to direct the use of the asset. SCE determines if an arrangement is a lease at contract inception. SCE includes both the lease and non-lease components as a single component and accounts for them as a lease for all classes of underlying assets, except energy storage underlying assets which were first contracted in 2020 and for which each component will be separately accounted for. 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 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, other than those that depend on an index or a rate or are in substance fixed payments. SCE's lease terms include options to extend or terminate the lease when it is reasonably certain that such options will be exercised. Operating leases are included in "Operating lease right-of-use assets," "Current portion of operating lease liabilities" and "Operating lease liabilities" on the consolidated balance sheets. Finance leases are included in "Utility property, plant and equipment," "Other current liabilities" and "Other deferred credits and other long-term liabilities" on the consolidated balance sheets.

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 discussion of SCE's contracts that are classified as operating and finance leases.

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Edison International Parent and Other's leases primarily relate to Edison Energy Group. The leases for Edison International Parent and Other 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. The performance shares granted during 2018 that are earned, have been or will be settled solely in cash. The performance shares granted in 2019 and 2020 that are earned, will be settled in common stock. Stock options, deferred stock units and restricted stock units are settled in common stock. However, for awards that are otherwise settled entirely in common stock, Edison International 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. However, with respect to the portion of the performance shares payable in common stock that are subject to market and 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. Awards paid in cash are classified as share-based liability awards and fair value is remeasured at each reporting date with the related compensation cost adjusted. 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.

SCE Dividends

CPUC holding company rules require that SCE's dividend policy be established by SCE's 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.

Effective January 1, 2020, the common equity component of SCE's CPUC authorized capital structure was increased from 48% to 52% on a weighted average basis over the January 1, 2020 to December 31, 2022 compliance period. Under AB 1054, the impact of SCE's contributions to the Wildfire Insurance Fund are excluded from the measurement of SCE's CPUC-jurisdictional authorized capital structure. For further information, see Note 12.

In May 2020, the CPUC issued a decision on SCE's application to the CPUC for 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 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. The temporary exclusion will lapse on May 7, 2022 or when a determination regarding cost recovery for the 2017/2018 Wildfire/Mudslide Events is made, whichever comes earlier. If the CPUC has not made a determination regarding cost recovery by May 7, 2022, SCE is permitted to file another application for a waiver of compliance with its equity ratio requirement. In the interim, 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. For further information, see Note 12.

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

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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 December 31, 2022.

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, SCE's Board of Directors evaluates available information, including when applicable, information pertaining to the 2017/2018 Wildfire/Mudslide Events, to ensure that the California law requirements for the declarations are met. On February 25, 2021, SCE declared a dividend to Edison International of $325 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, its ability to access the capital markets, and generate operating cash flows and earnings. If SCE incurs significant costs related to catastrophic wildfires, including the 2017/2018 Wildfire/Mudslide Events, 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.

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.

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EPS attributable to Edison International common shareholders was computed as follows:

			Years ended December 31,
(in millions, except per share amounts)			2020						2019						2018
Basic earnings (loss) per share – continuing operations:
Income (loss) from continuing operations attributable to common shareholders			$	739					$	1,284					$	(457)
Participating securities dividends			—						—						—
Income (loss) from continuing operations available to common shareholders			739						1,284						(457)
Weighted average common shares outstanding			373						340						326
Basic earnings (loss) per share – continuing operations			1.98						3.78						(1.40)
Diluted earnings (loss) per share – continuing operations:
Income (loss) from continuing operations attributable to common shareholders			739						1,284						(457)
Participating securities dividends			—						—						—
Income (loss) from continuing operations available to common shareholders			739						1,284						(457)
Income impact of assumed conversions			—						—						—
Income (loss) from continuing operations available to common shareholders and assumed conversions			739						1,284						(457)
Weighted average common shares outstanding			373						340						326
Incremental shares from assumed conversions1			1						1						—
Adjusted weighted average shares – diluted			374						341						326
Diluted earnings (loss) per share – continuing operations			$	1.98					$	3.77					$	(1.40)

1    Due to the loss reported for the year ended December 31, 2018, incremental shares were not included as the effect would be antidilutive.

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 9,066,753, 4,511,802 and 8,852,706 shares of common stock for the years ended December 31, 2020, 2019 and 2018, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.

Income Taxes

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 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" on the consolidated statements of income.

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.

Subsequent Events

In February 2021, SCE Recovery Funding LLC, a bankruptcy remote, wholly owned special purpose subsidiary of SCE, issued $338 million of Senior Secured Recovery Bonds, Series 2021-A, in three tranches of $138 million, 0.86% due 2033, $100 million, 1.94% due 2040, and $100 million, 2.51% due 2045 ("Recovery Bonds") and used the proceeds 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

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customers in SCE's service territory, associated with the AB 1054 Excluded Capital Expenditures ("Recovery Property"). The Recovery Bonds were payable only from and secured by the Recovery Property. SCE Recovery Funding LLC is considered a VIE and will be consolidated by SCE for financial reporting purposes, however, the Recovery Bonds 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. SCE used the proceeds it received from the sale of Recovery Property to reimburse itself for previously incurred AB 1054 Excluded Capital Expenditures, including the retirement of related debt.

New Accounting Guidance

Accounting Guidance Adopted

In June 2016, the Financial Accounting Standards Board ("FASB") issued an accounting standards update to require the use of the current expected credit loss model to measure impairment of financial assets measured at amortized cost, including trade and other receivables, and the use of an allowance to record estimated credit losses on available-for-sale debt securities. Edison International and SCE adopted this guidance on January 1, 2020 using the prospective adoption approach to available-for-sale debt securities and the modified retrospective approach to all other financial assets. The adoption of this guidance did not have a material impact on Edison International's and SCE's financial position or result of operations. See "Allowance for Uncollectible Accounts" and "Nuclear Decommissioning and Asset Retirement Obligations" above and Note 10 for further information.

In August 2018, the FASB issued an accounting standards update which aligns the requirement for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing costs incurred to develop or obtain internal use software. The guidance also clarified presentation requirements for reporting implementation costs in the financial statements. Edison International and SCE adopted the standard on January 1, 2020 using the prospective adoption approach. The adoption of this guidance did not have a material impact on Edison International's and SCE's financial position or result of operations.

In March 2020, the FASB issued an accounting standards update to provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions that reference London Inter-Bank Offered Rate ("LIBOR") or another reference rate expected to be discontinued because of reference rate reform. In January 2021, the FASB issued an update to this standard to clarify that certain optional expedients and exceptions for contract modifications and hedge accounting apply to derivatives that are affected by the reference rate transition. Edison International and SCE have adopted the standard as of April 1, 2020 prospectively. SCE generally does not use hedge accounting for derivative transactions. SCE has a term loan with a variable interest rate based on LIBOR. In addition, both Edison International and SCE have revolving credit facilities with a variable interest rate based on LIBOR. These agreements contain provisions that require an amendment if LIBOR can no longer be used. SCE also has certain preference stocks, for which the distributions will be payable at a floating rate referenced to LIBOR from 2022. As of December 31, 2020, both Edison International and SCE have not utilized any of the expedients and therefore there is no impact on adoption of the guidance, however, if contract amendments are made where LIBOR is no longer valid, both Edison International and SCE expect to utilize the expedients through the allowed period of December 31, 2022.

In August 2018, the FASB issued an accounting standards update to remove, modify and add certain disclosure requirements related to employer-sponsored defined benefit pension or other postretirement plans. The guidance removes disclosure requirements that are no longer considered cost beneficial, clarifies certain specific disclosure requirements and adds disclosure requirements identified as relevant. The modifications only affect annual period disclosures and must be applied on a retrospective basis to all periods presented. Edison International and SCE have adopted this guidance for the year ending December 31, 2020. The adoption of this guidance did not materially affect the annual disclosures related to employer-sponsored defined benefit pension or other postretirement plans. See Note 9 for further information.

Accounting Guidance Not Yet Adopted

In August 2020, the FASB issued an accounting standards update to simplify the accounting for certain financial instruments with characteristics of liabilities and equity. The amendments in this update affect entities that issue convertible instruments indexed to or potentially settled in an entity's own equity. This guidance also simplifies an entity's application of the derivatives scope exception for contracts in its own equity and amends certain aspects of the EPS guidance. The guidance is effective January 1, 2022 with early adoption permitted after January 1, 2021. Edison International and SCE do not expect the adoption of this standard will materially affect Edison International's and SCE's financial position or result of operations.

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Note 2.    Property, Plant and Equipment

SCE's property, plant and equipment included in the consolidated balance sheets is composed of the following:

			December 31,
(in millions)			2020						2019
Distribution			$	28,663					$	26,929
Transmission			15,669						14,720
Generation			3,709						3,664
General plant and other			5,129						4,583
Accumulated depreciation			(10,681)						(9,958)
			42,489						39,938
Construction work in progress			5,033						4,131
Nuclear fuel, at amortized cost			131						129
Total utility property, plant and equipment			$	47,653					$	44,198

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 the expected lives of the software, primarily ranging from 5 to 7 years and commencing upon operational use. Capitalized software costs, included in general plant and other above, were $1.2 billion and $1.0 billion at December 31, 2020 and 2019, respectively, and accumulated amortization was $0.6 billion and $0.4 billion, at December 31, 2020 and 2019, respectively. Amortization expense for capitalized software was $218 million, $190 million and $198 million in 2020, 2019 and 2018, respectively. At December 31, 2020, amortization expense is estimated to be $213 million, $168 million, $136 million, $82 million and $30 million for 2021 through 2025, 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, 2020:

(in millions)			Plant in Service			Construction Work in Progress			Accumulated Depreciation			Nuclear Fuel (at amortized cost)			Net Book Value			Ownership Interest
Transmission systems:
Eldorado			$	324		$	74		$	39		$	—		$	359		79		%
Pacific Intertie			346			—			74			—			272			50		%
Generating station:
Palo Verde (nuclear)			2,113			53			1,609			131			688			16		%
Total			$	2,783		$	127		$	1,722		$	131		$	1,319

In addition, SCE has ownership interests in jointly owned power poles with other companies.

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Note 3.    Variable Interest Entities

A VIE is defined as a legal entity that meets one of two conditions: (1) the equity owners do not have sufficient equity at risk, or (2) the holders of the equity investment at risk, as a group, lack any of the following three characteristics: decision-making 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. Commercial and operating activities include construction, operation and maintenance, fuel procurement, dispatch and compliance with regulatory and contractual requirements.

Variable Interest in VIEs that are not Consolidated

Power Purchase Agreements

SCE has PPAs that are classified as variable interests in VIEs, including agreements through which SCE provides the natural gas to fuel the plants and fixed price contracts for renewable energy. SCE has concluded that it is not the primary beneficiary of these VIEs since it does not control the commercial and operating activities of these entities. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is the operation and maintenance of the power plants.

As of the balance sheet date, the carrying amount of assets and liabilities in SCE's consolidated balance sheets that relate to involvement with VIEs 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 5,103 megawatts ("MW") and 4,497 MW at December 31, 2020 and 2019, respectively, and the amounts that SCE paid to these projects were $744 million and $833 million for the years ended December 31, 2020 and 2019, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.

Unconsolidated Trusts of SCE

SCE Trust II, Trust III, Trust IV, Trust V and Trust VI were formed in 2013, 2014, 2015, 2016 and 2017, respectively, for the exclusive purpose of issuing the 5.10%, 5.75%, 5.375%, 5.45% and 5.00% trust preference securities, respectively ("trust securities"). The trusts are VIEs. SCE has concluded that it is not the primary beneficiary of these VIEs as it does not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the trusts. SCE Trust II, Trust III, Trust IV, Trust V and Trust VI issued to the public trust securities in the face amounts of $400 million, $275 million, $325 million, $300 million and $475 million (cumulative, liquidation amounts of $25 per share), respectively, and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series G, Series H, Series J, Series K and Series L Preference Stock issued by SCE in the principal amounts of $400 million, $275 million, $325 million, $300 million and $475 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities.

The Series G, Series H, Series J, Series K and Series L Preference Stock and the corresponding trust securities do not have a maturity date. Upon any redemption of any shares of the Series G, Series H, Series J, Series K or Series L Preference Stock, a corresponding dollar amount of trust securities will be redeemed by the applicable trust (see Note 14 for further information). 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 board of directors declares and makes dividend payments on the related Preference Stock. The applicable trust will use any dividends it receives on the related Preference Stock to make its corresponding distributions on the applicable series of trust securities. If SCE does not make a dividend payment to any of these trusts, SCE would be prohibited from paying dividends on its common stock. SCE has fully and unconditionally guaranteed the payment of the trust securities and trust distributions, if and when SCE pays dividends on the related Preference Stock.

In September 2020, SCE Trust II redeemed $180 million of its trust securities from the public. The Trust II balance sheets as of December 31, 2020 and December 31, 2019 consisted of investments of $220 million and $400 million in the Series G Preference Stock, respectively, $220 million and $400 million of trust securities, respectively, and $10,000 each of common stock. The Trust III, Trust IV, Trust V and Trust VI balance sheets as of December 31, 2020 and December 31, 2019

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consisted of investments of $275 million, $325 million, $300 million, and $475 million in the Series H, Series J, Series K and Series L Preference Stock, respectively, $275 million, $325 million, $300 million, and $475 million of trust securities, respectively, and $10,000 each of common stock.

The following table provides a summary of the trusts' income statements:

						Years ended December 31,
(in millions)									Trust II						Trust III						Trust IV						Trust V						Trust VI
2020
Dividend income									$	20					$	16					$	17					$	16					$	24
Dividend distributions									20						16						17						16						24
2019
Dividend income									$	20					$	16					$	17					$	16					$	24
Dividend distributions									20						16						17						16						24
2018
Dividend income									$	20					$	16					$	17					$	16					$	24
Dividend distributions									20						16						17						16						24

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, 2020 and 2019, nonperformance risk was not material for Edison International and 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 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 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 – The fair value of SCE's Level 3 assets and liabilities is determined using the income approach through various models and techniques that require significant unobservable inputs. This level includes derivative contracts that trade infrequently such as congestion revenue rights ("CRRs"). 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

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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:

			December 31, 2020
(in millions)			Level 1						Level 2						Level 3						Netting and Collateral1						Total
Assets at fair value
Derivative contracts			$	—					$	6					$	120					$	(18)					$	108
Other			39						23						—						—						62
Nuclear decommissioning trusts:
Stocks2			1,908						—						—						—						1,908
Fixed Income3			519						2,113						—						—						2,632
Short-term investments, primarily cash equivalents			447						52						—						—						499
Subtotal of nuclear decommissioning trusts4			2,874						2,165						—						—						5,039
Total assets			2,913						2,194						120						(18)						5,209
Liabilities at fair value
Derivative contracts			—						10						12						(22)						—
Total liabilities			—						10						12						(22)						—
Net assets			$	2,913					$	2,184					$	108					$	4					$	5,209

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			December 31, 2019
(in millions)			Level 1						Level 2						Level 3						Netting and Collateral1						Total
Assets at fair value
Derivative contracts			$	—					$	19					$	83					$	(15)					$	87
Other			4						14						—						—						18
Nuclear decommissioning trusts:
Stocks2			1,765						—						—						—						1,765
Fixed Income3			738						2,024						—						—						2,762
Short-term investments, primarily cash equivalents			98						48						—						—						146
Subtotal of nuclear decommissioning trusts4			2,601						2,072						—						—						4,673
Total assets			2,605						2,105						83						(15)						4,778
Liabilities at fair value
Derivative contracts			—						11						5						(15)						1
Total liabilities			—						11						5						(15)						1
Net assets			$	2,605					$	2,094					$	78					$	—					$	4,777

1    Represents the netting of assets and liabilities under master netting agreements and cash collateral.

2    Approximately 71% and 72% of SCE's equity investments were located in the United States at December 31, 2020 and 2019, respectively.

3    Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $29 million and $46 million at December 31, 2020 and 2019, respectively.

4    Excludes net payables of $206 million and $111 million at December 31, 2020 and 2019, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

Edison International Parent and Other

Edison International Parent and Other assets measured at fair value and classified as Level 1 consisted of money market funds of $24 million and $31 million at December 31, 2020 and 2019, respectively. Edison International Parent and Other assets measured at fair value and classified as Level 2 consisted of short-term investments of $5 million at December 31, 2020. Edison International Parent and Other had no short-term investments as of December 31, 2019.

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:

						December 31,
(in millions)						2020						2019
Fair value of net assets at beginning of period						$	78					$	141
Purchases						8						6
Sales						(5)						(5)
Settlements						(117)						(60)
Total realized/unrealized gains (losses) 1,2						144						(4)
Fair value of net assets at end of period						$	108					$	78

1    Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities.

2    There were no material transfers into or out of Level 3 during 2020 and 2019.

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The following table sets forth SCE's valuation techniques and significant unobservable inputs used to determine fair value for significant Level 3 assets and liabilities:

			Fair Value (in millions)												Significant			Range (per MWh)			Weighted Average (per MWh)
			Assets						Liabilities			Valuation Technique			Unobservable Input
Congestion revenue rights
December 31, 2020			$	120					$	12		Auction prices			CAISO CRR auction clearing prices			$(9.67) - $300.47			$2.75
December 31, 2019			83						5			Auction prices			CAISO CRR auction clearing prices			(3.59) - 25.32			1.97

Level 3 Fair Value Uncertainty

For CRRs, increases or decreases in CAISO auction price 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 funds 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.

Nonrecurring Fair Value Measurements

Edison International assesses goodwill at the reporting unit level. The fair value of the Edison Energy reporting unit is classified as Level 3 and is estimated using the income approach. During the second quarter of 2020 and fourth quarter of 2019, Edison International evaluated the recoverability of goodwill and recorded impairment charges of Edison Energy's goodwill totaling $34 million ($25 million after-tax) and $25 million ($18 million after-tax), respectively. See Note 1 for further details.

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:

			December 31, 2020												December 31, 2019
(in millions)			Carrying Value1						Fair Value2						Carrying Value1						Fair Value2
Edison International			$	20,337					$	23,824					$	18,343					$	20,137
SCE			17,204						20,365						15,211						16,892

1     Carrying value is net of debt issuance costs.

2    The fair value of Edison International's and SCE's long-term debt is classified as Level 2.

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Note 5.    Debt and Credit Agreements

Long-Term Debt

The following table summarizes long-term debt (rates and terms are as of December 31, 2020) of Edison International and SCE:

			December 31,
(in millions)			2020						2019
Edison International Parent and Other:
Debentures and notes:
2022 – 2028 (2.40% to 5.75%)			$	3,150					$	3,150
Current portion of long-term debt			—						(400)
Unamortized debt discount/premium and issuance costs, net			(17)						(18)
Total Edison International Parent and Other			3,133						2,732
SCE:
First and refunding mortgage bonds:
2022 – 2050 (1.20% to 6.05%)			16,843						14,272
Pollution-control bonds:
2023 (2.63%)			135						752
Debentures and notes:
2029 – 2053 (5.06% to 6.65%)			306						306
Other long-term debt 1:			324						—
Current portion of long-term debt			(1,029)						(79)
Unamortized debt discount/premium and issuance costs, net			(80)						(119)
Total SCE			16,499						15,132
Total Edison International			$	19,632					$	17,864

1Subsequent to December 31, 2020, SCE issued first and refunding mortgage bonds which were used to partially pay down its commercial paper balance, see "Debt Financing Subsequent to December 31, 2020" for more information. Accordingly, SCE included the pay down amount of $324 million in other long-term debt.

Edison International and SCE long-term debt maturities over the next five years are as follows:

(in millions)			Edison International						SCE
2021			$	1,029					$	1,029
2022			1,064						364
2023			1,435						1,035
2024			500						—
2025			1,300						900

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, 2020, SCE's debt to total capitalization ratio was 0.51 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, 2020, Edison International consolidated debt to total capitalization ratio was 0.59 to 1.

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Credit Agreements and Short-Term Debt

The following table summarizes the status of the credit facilities at December 31, 2020:

(in millions, except for rates)
Execution date			Termination date			LIBOR plus (bps)			Use of proceeds			Commitment			Outstanding borrowings			Outstanding letters of credit			Amount available
Edison International Parent
June 2019			May 2024			128			Support commercial paper borrowings and general corporate purposes 1, 4			$	1,500		$	130		$	—		$	1370
Total Edison International Parent:												$	1,500		$	130		$	—		$	1,370
SCE
March 2020			March 2021			65			Finance a portion of the AB 1054 Capital Expenditures 2			$	800		$	495		$	—		$	305
May 2020			May 2021			150			Undercollections related to COVID-19 and general corporate purposes			1,500			—			—			1,500
June 2019			May 2024			108			Support commercial paper borrowings and general corporate purposes 3, 4			3,000			725			159			2,116
Total SCE:												$	5,300		$	1,220		$	159		$	3,921
Total Edison International:												$	6,800		$	1,350		$	159		$	5,291

1At December 31, 2020 Edison International Parent had $130 million outstanding commercial paper, net of discount, at a weighted-average interest rate of 0.42%. At December 31, 2019 Edison International Parent did not have any outstanding commercial paper.

2This credit facility may be extended for two 364-day periods, at the lenders' discretion. The aggregate maximum principal amount may be increased up to $1.1 billion provided that additional lender commitments are obtained.

3At December 31, 2020 and December 31, 2019, SCE had $725 million and $550 million outstanding commercial paper, net of discount, at a weighted-average interest rate of 0.43% and 2.24%, respectively. As of December 31, 2020, $324 million outstanding commercial paper was classified as long-term debt due to subsequent refinancing. See "Debt Financing Subsequent to December 31, 2020" for more information.

4The aggregate maximum principal amount under the SCE and Edison International Parent revolving credit facilities may be increased up to $4.0 billion and $2.0 billion, respectively, provided that additional lender commitments are obtained.

Term loan and other short-term debt

The following table summarizes the status of SCE's term loan and other short-term debt as of December 31, 2020:

(in millions, except for rates)

Issuance Date

Maturity

LIBOR plus (bps)

Use of Proceeds

Issuance Amount

Term loan

March 2020

March 2021

60

Fund a portion of the AB 1054 Excluded Capital Expenditures

$

475

Floating rate first and refunding mortgage bonds

December 2020

December 2021

27

Partial repayment of AB 1054 credit facility and commercial paper borrowings and for general corporate purposes

900

In March 2020, Edison International Parent borrowed $800 million under a term loan agreement due in March 2021 with a variable interest rate based on LIBOR plus 1.125%. The proceeds were used for general corporate purposes. In May 2020, Edison International repaid the outstanding balance of the term loan using the proceeds from issuance of common stock in a registered direct offering. Refer to Note 14 for details of the common stock issuance.

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Debt Financing Subsequent to December 31, 2020

In January 2021, SCE issued $750 million of 2.95% first and refunding mortgage bonds due in 2051 and $150 million of 2.25% first and refunding mortgage bonds due in 2030. The proceeds were primarily used to repay SCE's commercial paper borrowings and for general corporate purposes.

Note 6.    Derivative Instruments

Derivative financial instruments are used to manage exposure to commodity price risk. These risks 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.

Commodity Price Risk

Commodity price risk represents the potential impact that can be caused by a change in the market value of a particular commodity. SCE's electricity price exposure arises from energy purchased from and sold to wholesale markets as a result of differences between SCE's load requirements and the amount of energy delivered from its generating facilities and PPAs. SCE's natural gas price exposure arises from natural gas purchased for the Mountainview power plant and peaker plants, qualifying facilities contracts where pricing is based on a monthly natural gas index and PPAs in which SCE has agreed to provide the natural gas needed for generation, referred to as tolling arrangements.

Credit and Default Risk

Credit and default risk represent the potential impact that can be caused if a counterparty were to default on its contractual obligations and SCE would be exposed to spot markets for buying replacement power or selling excess power. In addition, SCE would be exposed to the risk of non-payment of accounts receivable, primarily related to the sales of excess power and realized gains on derivative instruments.

Certain power and gas contracts contain master netting agreements or similar agreements, which generally allow counterparties subject to the agreement to offset amounts when certain criteria are met, such as in the event of default. The objective of netting is to reduce credit exposure. Additionally, to reduce SCE's risk exposures 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 each of 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 net fair value of all derivative liabilities with these credit-risk-related contingent features was less than $1 million and $1 million as of December 31, 2020 and 2019, respectively, for which SCE has posted no collateral to its counterparties at the respective dates for its derivative liabilities and related outstanding payables for both periods. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2020, SCE would be required to post $3 million of additional collateral, all of which is related to outstanding payables.

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Fair Value of Derivative Instruments

SCE presents its derivative assets and liabilities 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. In addition, SCE has provided collateral in the form of letters of credit. Collateral requirements can vary depending upon the level of unsecured credit extended by counterparties, changes in market prices relative to contractual commitments and other factors. 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:

						December 31, 2020
						Derivative Assets																		Derivative Liabilities																		Net Asset
(in millions)						Short-Term1						Long-Term2						Subtotal						Short-Term3						Long-Term						Subtotal
Commodity derivative contracts
Gross amounts recognized						$	103					$	23					$	126					$	16					$	6					$	22					$	104
Gross amounts offset in the consolidated balance sheets						(12)						(6)						(18)						(12)						(6)						(18)						—
Cash collateral posted4						—						—						—						(4)						—						(4)						4
Net amounts presented in the consolidated balance sheets						$	91					$	17					$	108					$	—					$	—					$	—					$	108

						December 31, 2019
						Derivative Assets																		Derivative Liabilities																		Net Asset
(in millions)						Short-Term1						Long-Term2						Subtotal						Short-Term3						Long-Term						Subtotal
Commodity derivative contracts
Gross amounts recognized						$	94					$	8					$	102					$	14					$	2					$	16					$	86
Gross amounts offset in the consolidated balance sheets						(13)						(2)						(15)						(13)						(2)						(15)						—
Cash collateral posted4						—						—						—						—						—						—						—
Net amounts presented in the consolidated balance sheets						$	81					$	6					$	87					$	1					$	—					$	1					$	86

1Included in "Other current assets" on Edison International's and SCE's consolidated balance sheets.

2Included in "Other long-term assets" on Edison International's and SCE's consolidated balance sheets.

3Included in "Other current liabilities" on Edison International's and SCE's consolidated balance sheets.

4At December 31, 2020, SCE posted $17 million of cash, of which $4 million was offset against derivative liabilities and $13 million was reflected in "Other current assets" on the consolidated balance sheets. At December 31, 2019, SCE posted $24 million of cash, all of which was not offset against net derivative liabilities and 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 expects that such gains or losses will be part of the purchased power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are reported in cash flows from operating activities in the consolidated statements of cash flows.

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The following table summarizes the components of SCE's economic hedging activity:

						Years ended December 31,
(in millions)						2020						2019						2018
Realized gains (losses)						$	87					$	(7)					$	26
Unrealized gains (losses)						17						(74)						82

Notional Volumes of Derivative Instruments

The following table summarizes the notional volumes of derivatives used for SCE economic hedging activities:

						Economic Hedges
			Unit of			December 31,
Commodity			Measure			2020						2019
Electricity options, swaps and forwards			GWh			1,581						3,155
Natural gas options, swaps and forwards			Bcf			34						43
Congestion revenue rights			GWh			41,151						48,170

Note 7.    Revenue

•Earning activities – representing revenue authorized by the CPUC and FERC, which is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investment in generation, transmission and distribution assets. The annual revenue requirements are comprised of authorized operation and maintenance costs, depreciation, taxes and a return consistent with the capital structure. Also, included in earnings activities are revenues or penalties related to incentive mechanisms, other operating revenue and regulatory charges or disallowances.

•Cost-recovery activities – representing CPUC- and FERC- authorized balancing accounts, which allow for recovery of specific project or program costs, subject to reasonableness review or compliance with upfront standards. Cost-recovery activities include rates which provide recovery, subject to reasonableness review of, among other things, fuel costs, purchased power costs, public purpose related-program costs (including energy efficiency and demand-side management programs) and certain operation and maintenance expenses. SCE earns no return on these activities.

The following table is a summary of SCE's revenue:

			Years ended December 31,
			2020									2019									2018
(in millions)			Earning Activities			Cost- Recovery Activities			Total Consolidated			Earning Activities			Cost- Recovery Activities			Total Consolidated			Earning Activities			Cost-Recovery Activities			Total Consolidated
Revenues from contracts with customers1,2			$	6,920		$	5,539		$	12,459		$	6,512		$	4,655		$	11,167		$	6,519		$	5,611		$	12,130
Alternative revenue programs and other operating revenue3			548			539			1,087			166			973			1,139			41			440			481
Total operating revenue			$	7,468		$	6,078		$	13,546		$	6,678		$	5,628		$	12,306		$	6,560		$	6,051		$	12,611

1    In the absence of a 2018 GRC decision, SCE recognized CPUC revenue in 2018 and first quarter of 2019 based on the 2017 authorized revenue requirements adjusted mainly for the July 2017 cost of capital decision and Tax Reform. SCE recorded the impact of the 2018 GRC final decision in the second quarter of 2019, including a $289 million reduction in revenue related to 2018. These revenue adjustments are included in "Revenues from contracts with customers." See "Note 1. Summary of Significant Accounting Policies—Revenue Recognition—Regulatory Proceedings—2018 General Rate Case" for further information.

2    At December 31, 2020 and 2019, SCE's receivables related to contracts from customers were $1.5 billion and $1.1 billion, which included accrued unbilled revenue of $521 million and $488 million, respectively.

3    Includes differences between amounts billed and authorized levels for both the CPUC and FERC.

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Note 8.    Income Taxes

Current and Deferred Taxes

The components of income tax (benefit) expense by location of taxing jurisdiction are:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Current:
Federal			$	13					$	—					$	(57)					$	12					$	—					$	(51)
State			(22)						6						(155)						(26)						14						(93)
			(9)						6						(212)						(14)						14						(144)
Deferred:
Federal			(230)						(243)						(386)						(207)						(206)						(354)
State			(66)						(41)						(141)						(56)						(37)						(198)
			(296)						(284)						(527)						(263)						(243)						(552)
Total continuing operations			(305)						(278)						(739)						(277)						(229)						(696)
Discontinued operations1			—						—						(34)						—						—						—
Total			$	(305)					$	(278)					$	(773)					$	(277)					$	(229)					$	(696)

1     In the fourth quarter of 2018, Edison International and SCE recognized tax benefits related to a settlement with the California Franchise Tax Board for tax years 1994 – 2006. See further discussion in Tax Disputes below.

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The components of net accumulated deferred income tax liability are:

			Edison International												SCE
			December 31,
(in millions)			2020						2019						2020						2019
Deferred tax assets:
Property			$	590					$	478					$	540					$	435
Wildfire-related1			1,134						847						1,134						847
Nuclear decommissioning trust assets in excess of nuclear ARO liability			515						449						515						449
Loss and credit carryforwards2			1,991						1,515						683						253
Regulatory asset			841						739						841						739
Pension and postretirement benefits other than pensions, net			163						170						35						40
Other			513						408						527						416
Sub-total			5,747						4,606						4,275						3,179
Less: valuation allowance3			35						35						—						—
Total			5,712						4,571						4,275						3,179
Deferred tax liabilities:
Property			8,879						8,244						8,871						8,234
Regulatory liability			1,111						570						1,111						570
Nuclear decommissioning trust assets			515						449						515						449
Other			514						320						499						310
Total			11,019						9,583						10,996						9,563
Accumulated deferred income tax liability, net4			$	5,307					$	5,012					$	6,721					$	6,384

1     Relates to accrued estimated losses 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.

2     As of December 31, 2020, deferred tax assets for net operating loss and tax credit carryforwards are reduced by unrecognized tax benefits of $270 million and $190 million for Edison International and SCE, respectively.

3     As of December 31, 2020, Edison International has recorded a valuation allowance of $31 million for non-California state net operating loss carryforwards, and $4 million for California capital losses generated from sale of SoCore Energy in 2018, which are estimated to expire before being utilized.

4     Included 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:

			Edison International												SCE
			December 31, 2020
(in millions)			Loss Carryforwards						Credit Carryforwards						Loss Carryforwards						Credit Carryforwards
Expire in 2021			$	4					$	—					$	4					$	—
Expire between 2022 to 2025			31						—						26						—
Expire between 2029 to 2042			1,192						515						380						50
No expiration date1			509						10						413						—
Total			$	1,736					$	525					$	823					$	50

1Under Tax Reform, federal 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

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deferred income taxes includes $218 million and $212 million related to Capistrano Wind for 2020 and 2019, respectively. Under a 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 of these tax benefits when 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:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Income (loss) from continuing operations before income taxes			$	566					$	1,127					$	(1,089)					$	665					$	1,301					$	(885)
Provision for income tax at federal statutory rate of 21%			119						237						(229)						140						273						(186)
Increase in income tax from:
Items presented with related state income tax, net:
State tax, net of federal benefit			(61)						(22)						(168)						(52)						(13)						(155)
Property-related			(320)						(303)						(275)						(320)						(303)						(275)
Change related to uncertain tax positions1			(15)						—						(66)						(19)						—						(71)
Deferred tax re-measurement2			—						(88)						—						—						(88)						—
2018 GRC Final Decision			—						(80)						—						—						(80)						—
Corporate-owned life insurance cash surrender value			(8)						(8)						(8)						(8)						(8)						(8)
Other			(20)						(14)						7						(18)						(10)						(1)
Total income tax benefit from continuing operations			$	(305)					$	(278)					$	(739)					$	(277)					$	(229)					$	(696)
Effective tax rate			(53.9)		%				(24.7)		%				(67.9)		%				(41.7)		%				(17.6)		%				(78.6)		%

1    In 2020, Edison International and SCE recognized tax expense and benefit, respectively, primarily due to the re-measurement of uncertain tax positions related to the 2010 – 2012 California state tax filings currently under audit. In 2018, Edison International and SCE recognized tax benefits related to a settlement with the California Franchise Tax Board for tax years 1994 – 2006. See further discussion in Tax Disputes below.

2     Relates to changes in the allocation of deferred tax re-measurement between customers and shareholders as a result of a CPUC resolution issued in February 2019. The resolution determined that customers are only entitled to excess deferred taxes which were included when setting rates, while other deferred tax re-measurement belongs to the shareholders.

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.

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.

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Unrecognized Tax Benefits

The following table provides a reconciliation of unrecognized tax benefits for continuing and discontinued operations:

			Edison International																		SCE
			December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Balance at January 1,			$	370					$	338					$	432					$	282					$	249					$	331
Tax positions taken during the current year:
Increases			55						46						41						56						47						42
Tax positions taken during a prior year:
Increases1			274						6						—						4						6						—
Decreases2			(20)						(20)						(108)						(22)						(20)						(121)
Settlements with taxing authorities3			—						—						(27)						—						—						(3)
Balance at December 31,			$	679					$	370					$	338					$	320					$	282					$	249

1    Edison International recorded favorable tax positions in 2020 in connection with the Edison Mission Energy ("EME") bankruptcy that required a revaluation of the reserve for uncertain tax positions.

2     Decrease in 2018 was related to re-measurement as a result of a settlement with the California Franchise Tax Board for tax years 1994 – 2006.

3     In 2018, Edison International reached a settlement with the California Franchise Tax Board for tax years 1994 – 2006.

As of December 31, 2020, if recognized, $446 million of unrecognized tax benefits would impact Edison International's effective tax rate and $87 million of the unrecognized tax benefits would impact SCE's effective tax rate.

Tax Disputes

Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2016 – 2019 and 2013 – 2019, respectively. Tax years 2007 – 2012 are currently subject to a settlement proceeding with the California Franchise Tax Board. Edison International does not expect to resolve these tax years within the next 12 months. Any impacts cannot be reasonably estimated until further progress is made.

In the fourth quarter of 2018, Edison International recorded the impacts of a settlement reached with the California Franchise Tax Board for tax years 1994 – 2006 that resulted in a $65 million refund of tax and interest. This refund was received in the second quarter of 2019.

Accrued Interest and Penalties

The total amount of accrued interest and penalties related to income tax liabilities for continuing and discontinued operations are:

			Edison International												SCE
			Years ended December 31,
(in millions)			2020						2019						2020						2019
Accrued interest and penalties			$	52					$	56					$	23					$	29

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

			Edison International																		SCE
			December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Net after-tax interest and penalties tax expense (benefit)			$	4					$	4					$	(62)					$	6					$	3					$	(25)

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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
(in millions)			Years ended December 31,
2020			$	93					$	92
2019			82						81
2018			74						74

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 will no longer be eligible to participate in the Plan. In lieu of that, an additional non-contributory employer contribution will be 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 $55 million and $31 million, respectively, for the year ending December 31, 2021. Annual contributions made by SCE to most of SCE's 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, a regulatory asset has been recorded equal to the unfunded status. See Note 11 for further information.

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Information on pension plan assets and benefit obligations for continuing and discontinued operations is shown below.

			Edison International												SCE
			Years ended December 31,
(in millions)			2020						2019						2020						2019
Change in projected benefit obligation
Projected benefit obligation at beginning of year			$	4,139					$	3,880					$	3,662					$	3,431
Service cost			121						114						117						110
Interest cost			124						155						110						138
Actuarial loss			323						240						292						199
Benefits paid			(231)						(250)						(197)						(216)
Projected benefit obligation at end of year			$	4,476					$	4,139					$	3,984					$	3,662
Change in plan assets
Fair value of plan assets at beginning of year			$	3,755					$	3,321					$	3,541					$	3,124
Actual return on plan assets			584						611						551						576
Employer contributions			62						73						45						57
Benefits paid			(230)						(250)						(197)						(216)
Fair value of plan assets at end of year			4,171						3,755						3,940						3,541
Funded status at end of year			$	(305)					$	(384)					$	(44)					$	(121)
Amounts recognized in the consolidated balance sheets consist of 1:
Current liabilities			(24)						(19)						(2)						(2)
Long-term liabilities			(281)						(365)						(42)						(119)
			$	(305)					$	(384)					$	(44)					$	(121)
Amounts recognized in accumulated other comprehensive loss consist of:
Prior service cost			$	(1)					$	(1)					$	—					$	—
Net loss1			96						95						16						17
			95						94						16						17
Amounts recognized as a regulatory asset			12						87						12						87
Total not yet recognized as expense			$	107					$	181					$	28					$	104
Accumulated benefit obligation at end of year			$	4,238					$	3,968					$	3,776					$	3,529
Pension plans with an accumulated benefit obligation in excess of plan assets:
Projected benefit obligation			4,476						4,139						3,984						3,662
Accumulated benefit obligation			4,238						3,968						3,776						3,529
Fair value of plan assets			4,171						3,755						3,940						3,541
Weighted average assumptions used to determine obligations at end of year:
Discount rate			2.38		%				3.11		%				2.38		%				3.11		%
Rate of compensation increase			4.00		%				4.10		%				4.00		%				4.10		%

1    The SCE liability excludes a long-term payable due to Edison International Parent of $139 million and $133 million at December 31, 2020 and 2019, respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent. SCE's accumulated other comprehensive loss of $16 million and $17 million at December 31, 2020 and 2019, excludes net losses of $41 million and $37 million related to these benefits, respectively.

For Edison International and SCE, respectively, the 2020 actuarial losses are primarily related to $339 million and $305 million in losses from a decrease in the discount rate (from 3.11% as of December 31, 2019 to 2.38% as of December 31, 2020), partially offset by $117 million and $124 million in gains from other economic assumption changes; the 2019 actuarial losses are primarily related to $401 million and $373 million in losses from a decrease in the discount rate (from 4.19% as of

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December 31, 2018 to 3.11% as of December 31, 2019), partially offset by $157 million and $177 million in gains from other economic assumption changes.

Net periodic pension expense components for continuing operations are:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Service cost			$	121					$	114					$	126					$	119					$	111					$	123
Non-service cost
Interest cost			124						155						140						114						143						128
Expected return on plan assets			(215)						(205)						(228)						(203)						(194)						(214)
Amortization of prior service cost			2						2						3						1						2						3
Amortization of net loss			10						7						9						7						5						6
Regulatory adjustment (deferred)			16						(3)						15						16						(3)						15
Total non-service benefit			(63)						(44)						(61)						(65)						(47)						(62)
Total expense recognized			$	58					$	70					$	65					$	54					$	64					$	61

Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing operations:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Net loss			$	11					$	19					$	5					$	9					$	21					$	5
Amortization of net loss			(10)						(7)						(9)						(7)						(5)						(6)
Total recognized in other comprehensive loss			1						12						(4)						2						16						(1)
Total recognized in expense and other comprehensive loss			$	59					$	82					$	61					$	56					$	80					$	60

In accordance with authoritative guidance on rate-regulated enterprises, SCE records 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 pension expense for continuing operations:

			Years ended December 31,
			2020						2019						2018
Discount rate			3.11		%				4.19		%				3.46		%
Rate of compensation increase			4.10		%				4.10		%				4.10		%
Expected long-term return on plan assets			6.00		%				6.50		%				6.50		%
Interest crediting rate for cash balance account
Starting rate			3.61		%				4.46		%				4.36		%
Ultimate rate			5.00		%				5.75		%				5.75		%
Year ultimate rate is reached			2025						2022						2022

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

(in millions)			Edison International						SCE
2021			$	294					$	254
2022			297						259
2023			298						262
2024			299						266
2025			302						268
2026 – 2030			1,403						1,317

Postretirement Benefits Other Than Pensions ("PBOP(s)")

Employees hired prior to December 31, 2017 who are retiring 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, the Company 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 all 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.

The expected contributions (substantially all of which are expected to be made by SCE) for PBOP benefits are $9 million for the year ended December 31, 2021. 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 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 unfunded status is offset by a regulatory asset.

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

			Edison International												SCE
			Years ended December 31,
(in millions)			2020						2019						2020						2019
Change in benefit obligation
Benefit obligation at beginning of year			$	2,083					$	1,986					$	2,074					$	1,977
Service cost			38						30						37						30
Interest cost			63						77						63						77
Actuarial (gain) loss			(46)						70						(45)						70
Plan participants' contributions			29						29						29						29
Benefits paid			(94)						(109)						(94)						(109)
Benefit obligation at end of year			$	2,073					$	2,083					$	2,064					$	2,074
Change in plan assets
Fair value of plan assets at beginning of year			$	2,465					$	2,133					$	2,464					$	2,133
Actual return on assets			309						401						309						401
Employer contributions			8						11						8						10
Plan participants' contributions			29						29						29						29
Benefits paid			(94)						(109)						(93)						(109)
Fair value of plan assets at end of year			2,717						2,465						2,717						2,464
Funded status at end of year			$	644					$	382					$	653					$	390
Amounts recognized in the consolidated balance sheets consist of:
Long-term assets			$	663					$	393					$	663					$	402
Current liabilities			(10)						(11)						(10)						(12)
Long-term liabilities			(9)						—						—						—
			$	644					$	382					$	653					$	390
Amounts recognized in accumulated other comprehensive loss consist of:
Net loss			$	1					$	2					$	—					$	—
Amounts recognized as a regulatory liability			(671)						(416)						(671)						(416)
Total not yet recognized as income			$	(670)					$	(414)					$	(671)					$	(416)
Weighted average assumptions used to determine obligations at end of year:
Discount rate			2.67		%				3.32		%				2.67		%				3.32		%
Assumed health care cost trend rates:
Rate assumed for following year			6.50		%				6.50		%				6.50		%				6.50		%
Ultimate rate			5.00		%				5.00		%				5.00		%				5.00		%
Year ultimate rate reached			2029						2029						2029						2029

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Net periodic PBOP expense components for continuing operations are:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Service cost			$	38					$	30					$	37					$	37					$	30					$	37
Non-service cost
Interest cost			63						77						80						63						77						80
Expected return on plan assets			(119)						(111)						(121)						(119)						(111)						(122)
Amortization of prior service credit			(1)						(1)						(1)						(1)						(1)						(1)
Amortization of net gain			(29)						(17)						—						(29)						(17)						—
Regulatory adjustment			49						29						24						49						29						24
Total non-service benefit			(37)						(23)						(18)						(37)						(23)						(19)
Total expense			$	1					$	7					$	19					$	—					$	7					$	18

In accordance with authoritative guidance on rate-regulated enterprises, SCE records 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 for continuing operations:

			Years ended December 31,
			2020						2019						2018
Discount rate			3.32		%				4.35		%				3.70		%
Expected long-term return on plan assets			4.90		%				5.30		%				5.30		%
Assumed health care cost trend rates:
Current year			6.50		%				6.75		%				6.75		%
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:

(in millions)			Edison International						SCE
2021			$	83					$	82
2022			84						84
2023			86						86
2024			89						88
2025			90						90
2026 – 2030			475						472

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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 2020 pension plan assets were 23% for U.S. equities, 17% for non-U.S. equities, 45% for fixed income and 15% for opportunistic and/or alternative investments. Target allocations for 2020 PBOP plan assets (except for Represented VEBA which is 95% for fixed income and 5% for U.S. and non-U.S. equities) are 58% for U.S. and non-U.S. equities, 29% for fixed income and 13% 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 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 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 3%. 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 are 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

SCE'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 assumed average equity risk premium of 5% over cash. The forecasted return on private equity and opportunistic investments are estimated at a 4% 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 ("Master 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,

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U.S. treasury securities, 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, 2020 and 2019. 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 at Note 9 to the pension plan master trust investments table below.

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 Master Trust investments for Edison International and SCE that were accounted for at fair value as of December 31, 2020 by asset class and level within the fair value hierarchy:

(in millions)			Level 1						Level 2												NAV1						Total
U.S. government and agency securities2			$	151					$	1,006											$	—					$	1,157
Corporate stocks3			570						5												—						575
Corporate bonds4			—						601												—						601
Common/collective funds5			—						—												1,017						1,017
Partnerships/joint ventures6			—						—												569						569
Other investment entities7			—						—												137						137
Registered investment companies8			69						—												23						92
Interest-bearing cash			7						—												—						7
Other			—						39												—						39
Total			$	797					$	1,651											$	1,746					$	4,194
Receivables and payables, net																											(23)
Combined net plan assets available for benefits																											4,171
SCE's share of net plan assets																											$	3,940

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The following table sets forth the Master Trust investments that were accounted for at fair value as of December 31, 2019 by asset class and level within the fair value hierarchy:

(in millions)			Level 1						Level 2												NAV1						Total
U.S. government and agency securities2			$	146					$	992											$	—					$	1,138
Corporate stocks3			547						7												—						554
Corporate bonds4			—						572												—						572
Common/collective funds5			—						—												693						693
Partnerships/joint ventures6			—						—												471						471
Other investment entities7			—						—												130						130
Registered investment companies8			133						—												—						133
Interest-bearing cash			7						—												—						7
Other			—						79												—						79
Total			$	833					$	1,650											$	1,294					$	3,777
Receivables and payables, net																											(22)
Combined net plan assets available for benefits																											3,755
SCE's share of net plan assets																											$	3,541

1    These 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.

2    Level 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.

3    Corporate stocks are diversified. Performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (40%) and Morgan Stanley Capital International (MSCI) index (60%), at both December 31, 2020 and 2019.

4    Corporate bonds are diversified. At December 31, 2020 and 2019, respectively, this category includes $54 million and $45 million for collateralized mortgage obligations and other asset backed securities.

5 At December 31, 2020 and 2019, respectively, the common/collective assets were invested in equity index funds that seek to track performance of the Standard and Poor's 500 Index (37% and 35%) and Russell 1000 indexes (13% and 17%). In addition, at December 31, 2020 and 2019, respectively, 40% and 28% of the assets in this category are in index funds which seek to track performance in the MSCI All Country World Index exUS and 8% and 12% of this category are in non-index U.S. equity fund, which is actively managed.

6    At December 31, 2020 and 2019, respectively, 49% and 51% are invested in private equity funds with investment strategies that include branded consumer products and clean technology companies, 23% and 17% are invested in ABS including distressed mortgages and commercial and residential loans, 4% and 8% are invested in a broad range of financial assets in all global markets. 19% are invested in publicly traded fixed income securities for both periods.

7    At both December 31, 2020 and 2019, other investment entities were invested in (1) emerging market equity securities and (2) domestic mortgage backed securities.

8    Level 1 registered investment companies primarily consisted of a global equity mutual fund which seeks to outperform the MSCI World Total Return Index. In addition, investments included fixed income fund used for cash management at December 31, 2020.

At December 31, 2020 and 2019, respectively, approximately 59% and 56% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.

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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, 2020 by asset class and level within the fair value hierarchy:

(in millions)			Level 1						Level 2												NAV1						Total
U.S. government and agency securities2			$	380					$	30											$	—					$	410
Corporate stocks3			224						3												—						227
Corporate notes and bonds4			—						1,079												—						1,079
Common/collective funds5			—						—												693						693
Partnerships6			—						—												81						81
Registered investment companies7			65						—												—						65
Interest bearing cash			—						26												—						26
Other8			—						132												—						132
Total			$	669					$	1,270											$	774					$	2,713
Receivables and payables, net																											4
Combined net plan assets available for benefits																											2,717
SCE's share of net plan assets																											$	2,717

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, 2019 by asset class and level within the fair value hierarchy:

(in millions)			Level 1						Level 2												NAV1						Total
U.S. government and agency securities2			$	386					$	63											$	—					$	449
Corporate stocks3			242						2												—						244
Corporate notes and bonds4			—						885												—						885
Common/collective funds5			—						—												652						652
Partnerships6			—						—												68						68
Registered investment companies7			66						—												—						66
Interest bearing cash			—						17												—						17
Other8			2						101												—						103
Total			$	696					$	1,068											$	720					$	2,484
Receivables and payables, net																											(19)
Combined net plan assets available for benefits																											2,465
SCE's share of net plan assets																											$	2,464

1    These 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.

2    Level 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.

3    Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (70% and 68%) and the MSCI All Country World Index (30% and 32%) for 2020 and 2019, respectively.

4    Corporate notes and bonds are diversified and include approximately $170 million and $49 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2020 and 2019, respectively.

5    At December 31, 2020 and 2019, respectively, 70% and 74% of the common/collective assets are invested in index funds which seek to track performance in the MSCI All Country World Index Investable Market Index. 22% and 19% 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.

6    At December 31, 2020 and 2019, respectively, 46% and 55% 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. 36%

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and 28% of the remaining partnerships category are invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks. 18% and 15% are invested in a broad range of financial assets in all global markets.

7    At both December 31, 2020 and 2019, registered investment companies were primarily invested in a money market fund and exchange rate trade funds which seek to track performance of MSCI Emerging Market Index, Russell 2000 Index and international small cap equities.

8    Other includes $61 million and $66 million of municipal securities at December 31, 2020 and 2019, respectively.

At December 31, 2020 and 2019, respectively, approximately 66% and 65% 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, 2020, Edison International had approximately 23 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:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Stock-based compensation expense1:
Stock options			$	15					$	13					$	11					$	7					$	7					$	6
Performance shares			5						8						1						2						4						1
Restricted stock units			8						6						7						4						3						4
Other			1						2						2						—						—						—
Total stock-based compensation expense			29						29						21						13						14						11
Income tax benefits related to stock compensation expense			$	4					$	10					$	6					$	3					$	6					$	3

1    Reflected 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 four years of continuous service in equal annual increments, except for awards granted to retirement-eligible participants, which vest on an accelerated basis.

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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:

			Years ended December 31,
			2020						2019						2018
Expected terms (in years)			5.2						5.5						5.7
Risk-free interest rate			0.4% - 0.6%						1.6% - 2.3%						2.6% - 3.0%
Expected dividend yield			4.2% - 5.0%						3.3% - 4.0%						3.6% - 4.3%
Weighted average expected dividend yield			4.7%						3.9%						3.8%
Expected volatility			24.9% - 26.9%						21.7% -24.1%						20.9% - 21.9%
Weighted average volatility			25.0%						21.8%						20.9%

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 for 2020. The volatility period used was 63 months, 66 months and 68 months at December 31, 2020, 2019 and 2018, respectively.

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

									Weighted Average
			Stock Options						Exercise Price						Remaining Contractual Term (Years)						Aggregate Intrinsic Value (in millions)
Edison International:
Outstanding at December 31, 2019			9,278,677						$	62.27
Granted			1,993,954						68.60
Forfeited or expired			(203,340)						65.75
Exercised1			(359,908)						48.59
Outstanding at December 31, 2020			10,709,383						63.85						6.03
Vested and expected to vest at December 31, 2020			10,391,796						63.60						6.17						$	30
Exercisable at December 31, 2020			6,489,876						$	62.08					4.83						$	27
SCE:
Outstanding at December 31, 2019			4,934,702						$	61.01
Granted			1,053,923						68.27
Forfeited or expired			(189,691)						65.75
Exercised1			(302,911)						49.49
Affiliate transfers, net			(5,535)						63.36
Outstanding at December 31, 2020			5,490,488						62.85						5.86
Vested and expected to vest at December 31, 2020			5,325,052						62.50						5.98						$	20
Exercisable at December 31, 2020			3,361,238						$	60.41					4.56						$	19

1 Edison International and SCE recognized tax benefits of $2 million and $2 million, respectively, from stock options exercised in 2020.

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At December 31, 2020, total unrecognized compensation cost related to stock options and the weighted average period the cost is expected to be recognized are as follows:

			Edison International						SCE
Unrecognized compensation cost, net of expected forfeitures (in millions)			$	17					$	9
Weighted average period (in years)			2.3						2.3

Supplemental Data on Stock Options

			Edison International																		SCE
			Years ended December 31,
(in millions, except per award amounts)			2020						2019						2018						2020						2019						2018
Stock options:
Weighted average grant date fair value per option granted			$	8.18					$	8.80					$	8.21					$	8.16					$	8.83					$	8.22
Fair value of options vested			2						14						14						2						7						7
Value of options exercised			9						27						10						7						19						7

Performance Shares

A target number of contingent performance shares were awarded to executives in March 2020, 2019 and 2018 and vest at December 31, 2022, 2021 and 2020, 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.

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The following is a summary of the status of Edison International's nonvested performance shares:

			Equity Awards												Liability Awards
			Shares						Weighted Average Grant Date Fair Value						Shares						Weighted Average Grant Date Fair Value
Edison International:
Nonvested at December 31, 2019			119,843						$	66.03					113,186						$	67.30
Granted			120,938						67.55						—
Forfeited			(7,157)						66.76						(3,825)
Vested1			—						—						(109,361)
Nonvested at December 31, 2020			233,624						$	66.80					—						$	—
SCE:
Nonvested at December 31, 2019			63,172						$	66.27					58,399						$	67.34
Granted			64,133						67.15						—
Forfeited			(6,408)						66.78						(3,409)
Vested1			—						—						(54,578)
Affiliate transfers, net			(253)						71.27						(412)
Nonvested at December 31, 2020			120,644						$	66.70					—						$	—

1    Relates to performance shares that will be paid in 2021 as performance targets were met at December 31, 2020.

Restricted Stock Units

Restricted stock units were awarded to executives in March 2020, 2019 and 2018 and vest and become payable on January 3, 2023, January 3, 2022 and January 4, 2021, 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:

			Edison International												SCE
			Restricted Stock Units						Weighted Average Grant Date Fair Value						Restricted Stock Units						Weighted Average Grant Date Fair Value
Nonvested at December 31, 2019			311,682						$	66.11					159,985						$	66.16
Granted			119,038						68.58						63,042						68.24
Forfeited			(11,294)						63.90						(10,095)						63.93
Vested			(85,553)						78.94						(42,549)						79.11
Affiliate transfers, net			—						—						(1,963)						68.16
Nonvested at December 31, 2020			333,873						$	63.78					168,420						$	63.78

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

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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 of fair value of the trust investments):

			Longest Maturity Date						Amortized Cost												Fair Value
									December 31,
(in millions)									2020						2019						2020						2019
Stocks			—						N/A						N/A						$	1,908					$	1,765
Municipal bonds			2057						1,013						822						1,218						970
U.S. government and agency securities			2067						740						996						864						1,115
Corporate bonds			2070						460						597						550						679
Short-term investments and receivables/payables1			One-year						281						32						293						33
Total									$	2,494					$	2,447					$	4,833					$	4,562

1     Short-term investments include $138 million and $41 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by January 4, 2021 and January 2, 2020 as of December 31, 2020 and 2019, 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 $2.1 billion and $1.8 billion at December 31, 2020 and 2019, respectively.

Trust assets are used to pay income taxes. Deferred tax liabilities related to net unrealized gains were $515 million and $449 million at December 31, 2020 and December 31, 2019, respectively. Accordingly, the fair value of trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $4.3 billion and $4.1 billion at December 31, 2020 and December 31, 2019, respectively.

The following table summarizes the gains and losses for the trust investments:

			December 31,
(in millions)			2020			2019			2018
Gross realized gains			$	255		$	87		$	134
Gross realized losses			(6)			(2)			(27)
Net unrealized gains (losses) for equity securities			176			343			(233)

Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or 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, nuclear decommissioning and public purpose programs. Certain of these balancing accounts include a return on rate base of 7.68% and 7.61% in 2020 and 2019, 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.

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Regulatory Assets

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

			December 31,
(in millions)			2020						2019
Current:
Regulatory balancing and memorandum accounts			$	1,127					$	798
Power contracts			165						189
Other			22						22
Total current			1,314						1,009
Long-term:
Deferred income taxes, net of liabilities			4,475						4,026
Pension and other postretirement benefits			12						87
Power contracts			239						434
Unamortized investments, net of accumulated amortization1			114						119
Unamortized loss on reacquired debt			133						142
Regulatory balancing and memorandum accounts			1,794						981
Environmental remediation			247						237
Other			106						62
Total long-term			7,120						6,088
Total regulatory assets			$	8,434					$	7,097

1    Relates to a regulatory asset that earns a rate of return. See below for further information.

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, 2020. 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 power contracts primarily represent derivative contracts that were designated as normal purchases and normal sales contracts. The liabilities for these power contracts are amortized over the remaining contract terms, approximately 2 to 3 years. For further information, see Note 1.

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 2044 and 2027, respectively, and earned returns of 7.68% and 7.61% in 2020 and 2019, respectively.

SCE's net regulatory asset related to its unamortized loss 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.

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Regulatory Liabilities

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

			December 31,
(in millions)			2020						2019
Current:
Regulatory balancing and memorandum accounts			$	471					$	883
Energy derivatives			87						80
Other			11						9
Total current			569						972
Long-term:
Costs of removal			2,595						2,674
Re-measurement of deferred taxes			2,283						2,424
Recoveries in excess of ARO liabilities			1,930						1,569
Regulatory balancing and memorandum accounts			1,062						1,261
Other postretirement benefits			671						416
Other			48						41
Total long-term			8,589						8,385
Total regulatory liabilities			$	9,158					$	9,357

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 in depreciation and amounts collected in rates for those costs.

As a result of Tax Reform, SCE's deferred tax assets and liabilities were re-measured at December 31, 2017, resulting in the initial recording of regulatory liabilities. The amount was further adjusted for CPUC's final resolution in February 2019, which stated that customers are only entitled to re-measurement of deferred taxes that were included when setting rates (i.e. included in rate base), and that all other deferred tax re-measurements belong to shareholders. 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 taxes.

SCE's regulatory liabilities related to recoveries in excess of ARO liabilities represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the 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 other postretirement benefits represent the overfunded net actuarial gain. This amount will be refunded through rates charged to customers. 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.

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The following table summarizes the significant components of regulatory balancing and memorandum accounts included in the above tables of regulatory assets and liabilities:

			December 31,
(in millions)			2020						2019
Asset (liability)
Energy resource recovery account			$	(89)					$	(23)
Portfolio allocation balancing account			497						537
New system generation balancing account			(10)						85
Public purpose programs and energy efficiency programs			(1,130)						(1,244)
Base revenue requirement balancing account			622						(328)
Greenhouse gas auction revenue and low carbon fuel standard revenue			(125)						(196)
FERC balancing accounts			12						(127)
Wildfire and drought restoration accounts1			361						120
Wildfire-related memorandum accounts2			1,104						748
COVID-19-related memorandum accounts3			176						—
Other			(30)						63
Asset (Liability)			$	1,388					$	(365)

1     The wildfire and drought restoration accounts regulatory assets represent restorative costs that are recorded in a Catastrophic Event Memorandum Account ("CEMA").

2    The wildfire-related memorandum accounts 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 ("FHPMA") is 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. During 2019, the CPUC approved a Wildfire Mitigation Plan memorandum account to track costs incurred to implement SCE's Wildfire Mitigation Plan that are not currently reflected in SCE's revenue requirements, a Grid Safety and Resiliency Program Memorandum Account ("GSRPMA") to track the costs of SCE's GS&RP that are incremental to costs approved for recovery in SCE's 2018 GRC and a fire risk mitigation memorandum account to track costs related to the reduction of fire risk that are incremental to costs approved for recovery in SCE's 2018 GRC that are not tracked in any other wildfire-related memorandum account.

3    In July 2020, the CPUC approved establishment of the COVID-19 Pandemic Protection Memorandum Account ("CPPMA"), to track incremental consumer protection costs for residential and small commercial customers. A CEMA is used to track other incremental COVID-19 costs, including costs of sequestering employees at essential work locations. Both memorandum accounts were effective beginning March 2020.

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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, 2020, 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:

(in millions)															Total
2021															$	3,144
2022															3,066
2023															2,937
2024															2,349
2025															2,236
Thereafter															21,756
Total future commitments1															$	35,488

1Certain power purchase agreements are treated as operating or finance leases. For further discussion, see Note 13. Includes lease contracts commencing in 2021, 2022 and 2023 with future short-term lease expense of $242 million in 2021 and long-term minimum lease payments of $866 million.

Additionally, as of December 31, 2020, SCE has executed contracts (including capacity reduction contracts) that have not met the critical contract provisions that would increase contractual obligations by $29 million in 2021, $72 million in 2022, $93 million in 2023, $111 million in 2024, $111 million in 2025 and $1.2 billion thereafter, if all critical contract provisions are completed.

Costs incurred for PPAs were $3.8 billion in 2020, $3.7 billion in 2019 and $3.8 billion in 2018, 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:

(in millions)			2021						2022						2023						2024						2025						Thereafter						Total
Other contractual obligations			$	46					$	43					$	43					$	45					$	37					$	154					$	368

Costs incurred for other commitments were $80 million in 2020, $110 million in 2019 and $124 million in 2018. 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 various financial and performance guarantees and indemnity agreements which are issued in the normal course of business.

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 with respect to assets sold 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.

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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.

Southern California Wildfires and Mudslides

Wildfires in SCE's territory, including those where SCE's equipment may be alleged to be associated with the fire's ignition, have caused loss of life and substantial damage in recent years. Multiple factors have contributed to increased wildfire activity and faster progression of wildfires across SCE's service territory and in other areas of California. 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 wildfires. SCE has determined that approximately 27% of its service territory is in areas identified as high fire risk.

California has experienced unprecedented weather conditions in recent years and SCE's service territory remains susceptible to additional wildfire activity in 2021 and beyond. The worsening conditions across California increase the likelihood of wildfires, including those where SCE's equipment may be alleged to be associated with the fire's ignition. In response to worsening weather and fuel conditions and increased wildfire activity over the past several years, SCE has developed and is implementing its 2020 – 2022 Wildfire Mitigation Plan ("WMP") to reduce the risk of SCE equipment contributing to the ignition of wildfires. In addition, California has increased its investment in wildfire suppression capabilities.

In addition to the investments SCE is making through its WMP, SCE also uses its Public Safety Power Shutoffs ("PSPS") program to proactively de-energize power lines 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, impacting an aggregate of approximately 140,000 unique customers. In January 2021, the President of the CPUC sent SCE a letter expressing her concern regarding SCE's execution of PSPS in 2020 and notifying SCE that it must implement a PSPS action plan to reduce the impacts of PSPS on the customers and communities it serves. On a risk-informed basis, SCE is making efforts to reduce the frequency and impacts of PSPS in 2021 as compared to 2020, assuming that weather patterns in 2021 are similar to those experienced in 2020. SCE may be subject to mandated changes to, or restrictions on, its operational PSPS practices, regulatory fines and penalties, claims for damages and reputational harm if SCE does not execute PSPS in compliance with applicable rules and regulations or if it is determined that SCE has placed excessive reliance on PSPS.

Edison International and SCE accrued estimated losses of $1,328 million in 2020 for wildfire-related claims, net of expected insurance recoveries. The 2020 charge includes an increase in estimated losses for claims related to the 2017/2018 Wildfire/Mudslide Events (defined below) of $1,297 million, against which SCE has recorded expected recoveries through FERC electric rates of $84 million. The resulting charge was $1,213 million ($874 million after-tax). The 2020 charge also includes $31 million ($21 million after FERC recovery and after-tax) of expenses primarily associated with self-insured retention related to the 2019/2020 Wildfires (defined below).

Edison International and SCE have incurred material losses in connection with the 2017/2018 Wildfire/Mudslide Events, which are described below. Several wildfires have originated in Southern California subsequent to 2018, however, Edison International and SCE expect that any losses incurred in connection with these fires will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such losses after insurance recoveries will not be material.

Liability Overview

The extent of 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

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claims. Additionally, SCE could potentially be subject to fines for alleged violations of CPUC rules and state laws in connection with the ignition of a wildfire.

Final determinations of liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes. Even when investigations are still pending or 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.

2019/2020 Wildfires

Several wildfires significantly impacted portions of SCE's service territory in 2019 and 2020 (the wildfires that originated in Southern California in 2019 and 2020 where SCE's equipment may be alleged to be associated with the fire's ignition are referred to collectively as the "2019/2020 Wildfires"). Edison International and SCE expect that any losses incurred in connection with the 2019/2020 Wildfires will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such losses after insurance recoveries will not be material. As of December 31, 2020, Edison International and SCE had estimated losses (established at the lower end of the reasonably estimated range of expected losses) of $117 million reflected on their consolidated balance sheets related to the 2019/2020 Wildfires. As of the same date, Edison International and SCE also had assets for expected recoveries from insurance of $75 million and expected recoveries from FERC of $3 million on their consolidated balance sheets related to the 2019/2020 Wildfires.

One of the 2019/2020 Wildfires, 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 injuries to 8 individuals and one fatality. An investigation into the cause of the Saddle Ridge Fire is being led by the Los Angeles Fire Department. 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 possible losses that could be incurred cannot be estimated at this time. SCE has not accrued a charge for potential losses relating to the Saddle Ridge Fire.

Another of the 2019/2020 Wildfires, the "Bobcat Fire" was reported in the vicinity of Cogswell Dam in Los Angeles County, California in September 2020. The United States Forest Service ("USFS") has reported that the Bobcat Fire burned approximately 116,000 acres in Los Angeles County, destroyed an estimated 87 homes, 1 commercial property and 83 minor structures, damaged an estimated 28 homes and 19 minor structures, and resulted in injuries to 6 firefighters. In addition, the USFS has estimated suppression costs at $80 million. A camera in the vicinity of Cogswell Dam captured the initial stages of a fire with the first observed smoke approximately six minutes before an SCE circuit in the area experienced an anomaly (a relay). An investigation into the cause of the Bobcat Fire is being led by the USFS, and the USFS has taken a specific section of an SCE overhead conductor in the vicinity of Cogswell Dam into possession as part of its investigation. SCE understands that the USFS has also taken three tree branches in the area into possession. The SED is also conducting an investigation of the Bobcat Fire. SCE has accrued a charge for potential losses relating to the Bobcat Fire. The accrued charge corresponds to the lower end of the reasonably estimated range of expected losses that may be incurred in connection with the Bobcat Fire and is subject to change as additional information becomes available.

2017/2018 Wildfire/Mudslide Events

Wildfires in SCE's territory 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 California Department of Forestry and Fire Protection ("CAL FIRE"), have determined that the largest of the 2017 fires in SCE's territory originated on December 4, 2017, in the Anlauf Canyon area of Ventura County (the investigating agencies refer to this fire as the "Thomas Fire"), followed shortly thereafter by a second fire that originated near Koenigstein Road in the City of Santa Paula (the "Koenigstein Fire"). The December 4, 2017 fires eventually burned substantial acreage in both Ventura and Santa Barbara Counties. 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 territory, known as the "Woolsey Fire," originated in Ventura County and burned acreage in both Ventura and Los Angeles Counties. 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. Two additional fatalities have been associated with the Woolsey Fire. The Thomas Fire, the Koenigstein

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Fire, the Montecito Mudslides (defined below) and the Woolsey Fire are each referred to as a "2017/2018 Wildfire/Mudslide Event," and, collectively, referred to as the "2017/2018 Wildfire/Mudslide Events."

As described below, 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 (the "Montecito Mudslides") 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. Based on information available to SCE and consideration of the risks associated with litigation, Edison International and SCE expect to incur a material loss in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events. The 2017/2018 Wildfire/Mudslide Events are discussed further below.

As of December 31, 2020, Edison International and SCE had paid $1.8 billion in settlements and had estimated losses of $4.4 billion reflected on their consolidated balance sheets related to the 2017/2018 Wildfire/Mudslide Events, consisting of $2.2 billion subject to settlements executed after December 31, 2020 and $2.2 billion for remaining alleged and potential claims. As of the same date, Edison International and SCE also had assets for remaining expected recoveries from insurance of $708 million, reflected as a short-term asset, and through FERC electric rates of $89 million on their consolidated balance sheets related to the 2017/2018 Wildfire/Mudslide Events. The estimated losses for the 2017/2018 Wildfire/Mudslide Events do not include an estimate of any potential fines or penalties that could be levied against SCE in connection with the 2017/2018 Wildfire/Mudslide Events. Edison International and SCE are currently unable to reasonably estimate the magnitude of any such fines or penalties, or the associated timing if they were to be imposed. 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 as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of the 2017/2018 Wildfire/Mudslide Events, the complexities associated with fires that merge, whether inverse condemnation will be held applicable to SCE with respect to damages caused by the Montecito Mudslides, the preliminary nature of the litigation processes, the uncertainty in estimating damages that may be alleged, and the uncertainty as to how these factors impact future settlements.

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. See "Loss Estimates for Third Party Claims and Potential Recoveries from Insurance and through Electric Rates" below for additional information.

External Investigations and Internal Review

The VCFD and CAL FIRE have jointly issued reports concerning their findings regarding the causes of the Thomas Fire and the Koenigstein Fire. The reports did not address the causes of the Montecito Mudslides. SCE has also received a non-final redacted draft of a report from the VCFD regarding Woolsey Fire (the "Redacted Woolsey Report"). SCE anticipates that the VCFD will release its final report regarding the Woolsey Fire in 2021. The VCFD and CAL FIRE findings do not determine legal causation of or assign legal liability for the Thomas, Koenigstein or Woolsey Fires; final determinations of legal causation and liability would only be made during lengthy and complex litigation.

The CPUC's Safety and Enforcement Division ("SED") is also conducting investigations to assess SCE's compliance with applicable rules and regulations in areas impacted by the Thomas, Koenigstein and Woolsey Fires and the CPUC may initiate proceedings to investigate these matters after the SED's investigations are completed.

Edison International and SCE understand that the California Attorney General's Office has completed its investigation of the Thomas Fire without pursuing criminal charges. Edison International and SCE are aware of an ongoing investigation by the California Attorney General's Office of the Woolsey Fire for the purpose of determining whether any criminal violations have occurred. SCE could be subject to material fines, penalties, or restitution if it is determined that it failed to comply with applicable laws and regulations. SCE is not aware of any basis for felony liability with regards to the Thomas Fire, the Koenigstein Fire or the Woolsey Fire.

SCE's internal review into the facts and circumstances of each of the 2017/2018 Wildfire/Mudslide Events is complex and time consuming. 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 processes.

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Thomas Fire

On March 13, 2019, the VCFD and CAL FIRE jointly issued a report concluding, after ruling out other possible causes, that the Thomas Fire was started by SCE power lines coming into contact during high winds, resulting in molten metal falling to the ground. However, the report does not state that their investigation found molten metal on the ground. At this time, based on available information, SCE has not determined whether its equipment caused the Thomas Fire. Based on publicly available radar data showing a smoke plume in the Anlauf Canyon area emerging in advance of the report's indicated start time, SCE believes that the Thomas Fire started at least 12 minutes prior to any issue involving SCE's system and at least 15 minutes prior to the start time indicated in the report. SCE is continuing to assess the extent of damages that may be attributable to the Thomas Fire.

Koenigstein Fire

On March 20, 2019, the VCFD and CAL FIRE jointly issued a report finding that the Koenigstein Fire was caused when an energized SCE electrical wire separated and fell to the ground along with molten metal particles and ignited the dry vegetation below. As previously disclosed, SCE believes that its equipment was associated with the ignition of the Koenigstein Fire. SCE is continuing to assess the extent of damages that may be attributable to the Koenigstein Fire.

Montecito Mudslides

SCE's internal review includes inquiry into whether the Thomas and/or Koenigstein Fires proximately caused or contributed to the Montecito Mudslides, whether, and to what extent, the Thomas and/or Koenigstein Fires were responsible for the damages in the Montecito area and other factors that potentially contributed to the losses that resulted from the Montecito Mudslides. Many other factors, including, but not limited to, weather conditions and insufficiently or improperly designed and maintained debris basins, roads, bridges and other channel crossings, could have proximately caused, contributed to or exacerbated the losses that resulted from the Montecito Mudslides.

At this time, based on available information, SCE has not been able to determine whether the Thomas Fire or the Koenigstein Fire, or both, were responsible for the damages in the Montecito area. In the event that SCE is determined to have caused the fire that spread to the Montecito area, SCE cannot predict whether, if fully litigated, the courts would conclude that the Montecito Mudslides were caused or contributed to by the Thomas and/or Koenigstein Fires or that SCE would be liable for some or all of the damages caused by the Montecito Mudslides.

Woolsey Fire

SCE's internal review into the facts and circumstances of the Woolsey Fire is ongoing. SCE has reported to the CPUC that there was an outage on SCE's electric system in the vicinity of where the Woolsey Fire reportedly began on November 8, 2018. SCE is aware of witnesses who saw fire in the vicinity of SCE's equipment at the time the fire was first reported. While SCE did not find evidence of downed electrical wires on the ground in the suspected area of origin, it observed a pole support wire in proximity to an electrical wire that was energized prior to the outage.

The Redacted Woolsey Report states that the VCFD investigation team determined that electrical equipment owned and operated by SCE was the cause of the Woolsey Fire. Absent additional evidence, SCE believes that it is likely that its equipment was associated with the ignition of the Woolsey Fire. SCE expects to obtain and review additional information and materials in the possession of CAL FIRE and others during the course of its internal review and the Woolsey Fire litigation process, including SCE equipment that has been retained by CAL FIRE.

Litigation

Multiple 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. Because potential plaintiffs can still timely file claims related to the 2017/2018 Wildfire/Mudslide Events, SCE expects to be the subject of additional lawsuits related to the events. The litigation could take a number of years to be resolved because of the complexity of the matters and number of plaintiffs.

As of February 18, 2021, SCE was aware of at least 295 lawsuits, representing approximately 4,000 plaintiffs, related to the Thomas and Koenigstein Fires naming SCE as a defendant. One hundred fifty of the 295 lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. At least four of the lawsuits were filed as purported class actions. 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

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public utilities and health and safety codes. An initial trial for a limited number of plaintiffs, sometimes referred to as a bellwether trial, on certain fire only matters is currently scheduled for July 19, 2021. The bellwether trial date may be further delayed to provide SCE and certain of the individual plaintiffs in the Thomas and Koenigstein Fire litigation the opportunity to pursue settlements of claims under a program adopted to promote an efficient and orderly settlement process.

Seventy-two of the 295 lawsuits mentioned in the paragraph above allege that SCE has responsibility for the Thomas and/or Koenigstein Fires and that the Thomas and/or Koenigstein Fires proximately caused the Montecito Mudslides, resulting in the plaintiffs' claimed damages. Forty of the 72 Montecito Mudslides lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. In addition to other causes of action, some of the Montecito Mudslides lawsuits also allege personal injury and wrongful death. A bellwether jury trial previously scheduled for October 12, 2020 was vacated due to the wide-spread disruption being caused by the COVID-19 pandemic.

As of February 18, 2021, SCE was aware of at least 301 lawsuits, representing approximately 6,000 plaintiffs, related to the Woolsey Fire naming SCE as a defendant. Two hundred forty-three of the 301 lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. At least two of the lawsuits were filed as purported class actions. 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. A bellwether jury trial is currently scheduled for June 1, 2021.

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. On October 4, 2018, the Superior Court denied Edison International's and SCE's challenge to the application of inverse condemnation to SCE with respect to the Thomas and Koenigstein Fires and, on February 26, 2019, the California Supreme Court denied SCE's petition to review the Superior Court's decision. 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. These cross-claims in the Montecito Mudslides litigation were not released as part of the Local Public Entity Settlements (as defined below).

Additionally, in September 2018, a derivative lawsuit for breach of fiduciary duties and unjust enrichment was filed in the Los Angeles Superior Court against certain current and former members of the Boards of Directors of Edison International and SCE. Edison International and SCE are identified as nominal defendants in the action. The derivative lawsuit generally alleges that the individual defendants violated their fiduciary duties by causing or allowing SCE to operate in an unsafe manner in violation of relevant regulations, resulting in substantial liability and damage from the Thomas and Koenigstein Fires and the Montecito Mudslides. The lawsuit is currently stayed.

In November 2018, a purported class action lawsuit alleging securities fraud and related claims was filed in federal court against Edison International, SCE and certain current and former officers of Edison International and SCE. The plaintiff alleges that Edison International and SCE made false and/or misleading statements in filings with the Securities and Exchange Commission by failing to disclose that SCE had allegedly failed to maintain its electric transmission and distribution networks in compliance with safety regulations, and that those alleged safety violations led to fires that occurred in 2017 and 2018, including the Thomas Fire and the Woolsey Fire.

In January 2019, two separate derivative lawsuits alleging breach of fiduciary duties, securities fraud, misleading proxy statements, unjust enrichment, and related claims were filed in federal court against certain current and former members of the Boards of Directors and certain current and former officers of Edison International and SCE. Edison International and SCE are named as nominal defendants in those actions. The derivative lawsuits generally allege that the individual defendants breached their fiduciary duties and made misleading statements or allowed misleading statements to be made (i) between March 21, 2014 and August 10, 2015, with respect to certain ex parte communications between SCE and CPUC decision-makers concerning the settlement of the San Onofre Order Instituting Investigation proceeding (the "San Onofre OII") and (ii) from February 23, 2016 to the present, concerning compliance with applicable laws and regulations concerning electric system maintenance and operations related to wildfire risks. The lawsuits generally allege that these breaches of duty and misstatements led to substantial liability and damage resulting from the disclosure of SCE's ex parte communications in connection with the San Onofre OII settlement, and from the 2017/2018 Wildfire/Mudslide Events. The lawsuits are currently stayed.

Settlements

In the fourth quarter of 2019, SCE paid $360 million to a number of local public entities to resolve those parties' collective claims arising from the 2017/2018 Wildfire/Mudslide Events (the "Local Public Entity Settlements").

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In the third quarter of 2020, Edison International and SCE entered into an agreement (the "TKM Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Thomas Fire, Koenigstein Fire and Montecito Mudslides litigation (the "TKM Subrogation Plaintiffs") collective claims arising from the Thomas Fire, Koenigstein Fire or Montecito Mudslides have been resolved. Under the TKM Subrogation Settlement, SCE paid the TKM Subrogation Plaintiffs an aggregate of $1.2 billion in October 2020 and also agreed to pay $0.555 for each dollar in claims to be paid by the TKM Subrogation Plaintiffs to their policy holders on or before July 15, 2023, up to an agreed upon cap.

In January 2021, Edison International and SCE entered into an agreement (the "Woolsey Subrogation Settlement") under which all of the insurance subrogation plaintiffs' in the Woolsey Fire litigation (the "Woolsey Subrogation Plaintiffs") collective claims arising from the Woolsey Fire have been resolved. Under the Woolsey Subrogation Settlement, SCE agreed to pay the Woolsey Subrogation Plaintiffs an aggregate of $2.2 billion by April 22, 2021. SCE has also agreed to pay $0.67 for each dollar in claims to be paid by the Woolsey Subrogation Plaintiffs to their policy holders on or before July 15, 2023, up to an agreed upon cap.

SCE has also entered into settlements with approximately one thousand individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation. In 2020 SCE entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $300 million to those individual plaintiffs. Between December 31, 2020 and February 18, 2021, SCE also entered into settlements with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation under which it agreed to pay an aggregate of approximately $80 million to those individual plaintiffs.

Edison International and SCE did not admit wrongdoing or liability as part of any of the settlements described above.

Other claims and potential claims related to the 2017/2018 Wildfire/Mudslide Events remain. SCE continues to explore reasonable settlement opportunities with other plaintiffs in the outstanding 2017/2018 Wildfire/Mudslide Events litigation.

Loss Estimates for Third Party Claims and Potential Recoveries from Insurance and through Electric Rates

At December 31, 2019, Edison International and SCE were unable to determine a best estimate of expected losses within a reasonably estimated range and therefore Edison International's and SCE's consolidated balance sheets included estimated losses, established at the lower end of the reasonably estimated range of expected losses, of $4.5 billion for the 2017/2018 Wildfire/Mudslide Events. In light of the TKM Subrogation Settlement and increased settlement activity with individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation, among other things, management established a best estimate of expected potential losses for alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events litigation in the third quarter of 2020. As a result, Edison International and SCE recorded a charge of $1.3 billion in September 2020 related to the 2017/2018 Wildfire/Mudslide Events, against which SCE recorded expected recoveries through FERC electric rates of $84 million. The resulting net pre-tax charge to earnings was $1.2 billion ($874 million after-tax).

At December 31, 2020 and December 31, 2019, Edison International's and SCE's consolidated balance sheets include accrued estimated losses of $4.4 billion and $4.5 billion, respectively, for the 2017/2018 Wildfire/Mudslide Events. The following table presents changes in estimated losses since December 31, 2019:

(in millions)
Loss estimate balance at December 31, 2019			$	4,541
Increase in accrued estimated losses to reflect best estimate			1,297
Amounts paid			(1,455)
Loss estimate balance at December 31, 20201			4,383

1 At December 31, 2020, $2,231 million in current liabilities, wildfire-related claims, on Edison International's and SCE's consolidated balance sheets includes an estimate for claims brought by insurance subrogation plaintiffs in the Woolsey Fire litigation, which were subsequently settled on January 22, 2021 for $2,212 million, and $19 million of other settlements executed in connection with the 2017/2018 Wildfire/Mudslide Events. At December 31, 2020, the $2,281 million included in deferred credits and other liabilities, wildfire-related claims on Edison International's and SCE's consolidated balance sheets includes Edison International and SCE's best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events after giving effect to the Woolsey Subrogation Settlement of $2,152 million and other wildfire-related claims estimates of $129 million.

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For the years-ended December 31, 2020 and 2019, Edison International's and SCE's consolidated statements of income include charges for the estimated losses, net of expected recoveries from insurance and FERC customers, related to the 2017/2018 Wildfire/Mudslide Events as follows:

			Year ended December 31,
(in millions)			2020						2019
Charge for wildfire-related claims			$	1,297					$	232
Expected revenue from FERC customers			(84)						(14)
Total pre-tax charge			1,213						218
Income tax benefit			(339)						(61)
Total after-tax charge			$	874					$	157

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. Edison International and SCE record a receivable for insurance recoveries when recovery of a recorded loss is determined to be probable. The following table presents changes in expected insurance recoveries associated with the estimated losses for the 2017/2018 Wildfire/Mudslide Events since December 31, 2019:

(in millions)
Balance at December 31, 20191			$	1,710
Insurance recoveries			(1,002)
Balance at December 31, 2020			$	708

1 At December 31, 2019, the balance was included in "Other long-term assets" on the consolidated balance sheets of SCE and Edison International.

At December 31, 2020, SCE had no remaining expected recoveries from insurance for the Thomas Fire, Koenigstein Fire and Montecito Mudslides litigation. At December 31, 2020, SCE had approximately $708 million remaining in expected recoveries from insurance for the Woolsey Fire litigation, included in "Insurance receivable" and "Insurance receivable from affiliate" on the consolidated balance sheets of SCE and "Insurance receivable" on the consolidated balance sheets of Edison International. SCE expects that this insurance will be exhausted after expected recoveries for the Woolsey Subrogation Settlement.

In total, SCE has accrued estimated losses of $6.2 billion, has paid or agreed to pay $4.1 billion in settlements and has

recovered $1.3 billion, and has approximately $708 million remaining in expected recoveries, from its insurance carriers through February 18, 2021 in relation to the 2017/2018 Wildfire/Mudslide Events.

Recovery of SCE's actual 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 when 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 has sought recovery for uninsured wildfire-related costs is SDG&E's requests for cost recovery related to 2007 wildfire activity, where the FERC allowed 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 SDG&E did not meet the CPUC's prudency standard. As a result, while SCE does not agree with the CPUC's decision, it believes that the CPUC's interpretation and application of the prudency standard to SDG&E creates substantial uncertainty regarding how that standard will be applied to an investor-owned utility in future wildfire cost-recovery proceedings for fires ignited prior to July 12, 2019. SCE will continue to evaluate the probability of recovery based on available evidence, including judicial, legislative and regulatory decisions, including any CPUC decisions illustrating the interpretation and/or application of the prudency standard when making determinations regarding recovery of uninsured wildfire-related costs. While the CPUC has not made a determination regarding SCE's prudency relative to any of the 2017/2018 Wildfire/Mudslide Events, SCE is unable to conclude, at this time, that uninsured CPUC-jurisdictional wildfire-related costs are probable of recovery through electric rates. SCE would record a regulatory asset at the time it obtains sufficient information to support a conclusion that recovery is probable. SCE will seek CPUC-jurisdictional rate recovery of prudently-incurred, actual losses realized in connection with the 2017/2018 Wildfire/Mudslide Events in excess of available insurance.

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SCE will seek recovery of the CPUC portion of any uninsured wildfire-related costs through its WEMA or its CEMA. In July 2019, SCE filed a CEMA application with the CPUC to seek recovery of, among other things, approximately $6 million in costs incurred to restore service to customers and to repair, replace and restore buildings and SCE's facilities damaged or destroyed as a result of the Thomas and Koenigstein Fires. SCE continues to incur costs for reconstructing its system and restoring service to structures that were damaged or destroyed by these two fires and plans to file additional applications with the CPUC to recover such costs. See "Recovery of Wildfire-Related Costs" below.

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 of $233 million within the FERC balancing account. This was the FERC portion of the estimated losses accrued. As of December 31, 2020, collections have reduced the regulatory assets remaining in the FERC balancing account to $89 million.

Current Wildfire Insurance Coverage

SCE had 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 $115 million of co-insurance and $50 million of 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 may occur during the period July 1, 2020 through June 30, 2021, subject to up to $80 million of co-insurance and $50 million of self-insured retention, which results in net coverage of approximately $870 million. Various coverage limitations within the policies that make up SCE's wildfire insurance coverage could result in additional material self-insured costs, for instance in the event of multiple wildfire occurrences during a policy period. SCE believes that its insurance coverage for the July 1, 2020 through June 30, 2021 period meets its obligation to maintain reasonable insurance coverage under AB 1054.

Wildfire insurance expense in 2020, prior to any regulatory deferrals, was approximately $450 million. Wildfire insurance expense in 2019, prior to any regulatory deferrals, was approximately $400 million. Calendar year insurance expense reflects the portion of premiums attributable to policy coverage in that calendar year.

SCE tracks incremental insurance premium, self-insured retention and co-insurance costs related to wildfire liability insurance policies as well as other wildfire-related costs, including claims and legal costs, in its WEMA. In July 2019, SCE filed a WEMA application with the CPUC to seek recovery of an aggregate of $505 million, consisting of $478 million in wildfire insurance premium costs that had been incurred or were to be incurred before July 1, 2020 in excess of premiums approved in the 2018 GRC and the corresponding financing costs. In September 2020, the CPUC approved SCE's July 2019 WEMA application and authorized SCE to collect a total revenue requirement of $505 million over a two-year period. SCE included the authorized revenue requirement in rates in October 2020. In December 2020, SCE filed another WEMA application with the CPUC to seek recovery of an aggregate of $214 million, consisting of $204 million in wildfire insurance premium costs in excess of premiums approved in the 2018 GRC, representing wildfire insurance premiums for July 1, 2020 through December 31, 2020, the corresponding financing costs, memorandum account interest and a prior period premium adjustment.

SCE's cost of obtaining wildfire insurance coverage has increased significantly in recent years as a result of, among other things, the number of recent and significant wildfire events throughout California and the application of inverse condemnation to investor-owned utilities. As such, while SCE is required to maintain reasonable insurance coverage under AB 1054, SCE may not be able to obtain a reasonable amount of wildfire insurance, at a reasonable cost, for future policy periods.

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

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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 have 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. The summary of the wildfire legislation below is based on SCE's interpretation of AB 1054. A lawsuit challenging the validity of AB 1054 was filed in federal court on July 19, 2019. Edison International and SCE are unable to predict the outcome of this lawsuit.

    AB 1054 Prudency Standard

Under AB 1054, the CPUC must apply a new standard 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 the ratepayers, and the requirements of governmental agencies. AB 1054 also provides 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 reasonable. 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 standard will survive the termination of the Wildfire Insurance Fund.

Utilities participating in the Wildfire Insurance Fund are not required to reimburse the fund for amounts withdrawn from the fund that the CPUC finds were prudently incurred and can recover such prudently incurred 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 utility for payment of third-party damage 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 to have been caused by a utility.

SCE and SDG&E collectively made their initial contributions totaling approximately $2.7 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 to the Wildfire Insurance Fund through annual contributions to the fund over a 10-year period, of which they have made two annual contributions totaling approximately $600 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 made an initial contribution of approximately $2.4 billion to the Wildfire Insurance Fund in September 2019 and committed to make ten annual contributions of approximately $95 million per year to the fund, by no later than January 1 of each year. Through December 31, 2020, SCE has contributed approximately $2.6 billion to the Wildfire Insurance Fund. During 2020 SCE amortized its contributions to the Wildfire Insurance Fund over 10 years, based on evaluation of the fund's expected life based on actual fire experience to December 31, 2020. SCE expects the life of the fund to be 15 years from July 12, 2019 which will be reflected prospectively in amortization expense from January 1, 2021. SCE's contributions to the Wildfire Insurance Fund will not be 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. See Note 1 for information on the accounting impact of SCE's contributions to the Wildfire Insurance Fund.

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Reimbursement from Wildfire Insurance Fund and AB 1054 Liability Cap

Participating investor-owned utilities will be reimbursed from the Wildfire Insurance Fund for eligible claims, 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, in some instances, to the AB 1054 Liability Cap (as defined below). 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 ("AB 1054 Liability Cap"). Based on SCE's forecasted weighted-average 2021 rate base and using the equity portion of SCE's CPUC authorized capital structure of 52%, SCE's requirement to reimburse the Wildfire Insurance Fund for eligible claims disallowed in 2021 would be capped at approximately $3.2 billion.

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 the submission of certain required safety information, including an approved wildfire mitigation plan ("WMP"). On September 17, 2020, SCE obtained a safety certification that will be valid for 12 months. Notwithstanding its 12-month term, if SCE requests a new safety certification prior to the expiration of its current safety certification, then its current safety certification will remain valid until the CPUC's Wildfire Safety Division ("WSD") acts on SCE's request for a new safety certification.

Under AB 1054, SCE is required to submit a WMP to the CPUC at least once every three years for review and approval. Beginning in 2020, each such plan was required to cover at least a three-year period. SCE filed its 2020 – 2022 WMP in February 2020. In June 2020 the CPUC ratified the WSD's conditional approval of SCE's 2020 – 2022 WMP. The approval is conditioned on SCE providing requested information to the WSD, including additional descriptions of how SCE is implementing, and will implement, certain requirements imposed by the WSD. SCE filed an update to its 2020 – 2022 WMP on February 5, 2021 to, among other things, report on implementation of its plan in 2020 and describe new and ongoing wildfire mitigation activities.

    Capital Expenditure Requirement

Under AB 1054, approximately $1.6 billion of spending by SCE on wildfire risk mitigation capital expenditures made after August 1, 2019, cannot be included in the equity portion of SCE's rate base ("AB 1054 Excluded Capital Expenditures"). SCE can apply for irrevocable orders from the CPUC to finance these AB 1054 Excluded Capital Expenditures, including through the issuance of securitized bonds, and can recover any prudently incurred financing costs. In November 2020, the CPUC issued an irrevocable order permitting SCE to finance approximately $340 million, comprised of AB 1054 Excluded Capital Expenditures incurred in connection with GS&RP and prudently incurred financing costs, through the issuance of securitized bonds. As of December 31, 2020, SCE has spent $1.3 billion on AB 1054 Excluded Capital Expenditures and expects to spend the remainder of the AB 1054 Excluded Capital Expenditures in the first quarter of 2021. SCE issued securitized bonds in the amount of $338 million in February 2021 and expects to seek additional irrevocable orders from the CPUC to finance the remaining AB 1054 Excluded Capital Expenditures.

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 lower 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, 2020, SCE's recorded estimated minimum liability to remediate its 25 identified material sites (sites with a liability balance as of December 31, 2020, in which the upper end of the range of the costs is at least $1 million) was $255 million, including $173 million related to San Onofre. In addition to these sites, SCE also has 15 immaterial sites with a

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liability balance at December 31, 2020 for which the total minimum recorded liability was $4 million. Of the $259 million total environmental remediation liability for SCE, $247 million has been recorded as a regulatory asset. SCE expects to recover $40 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 $207 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.

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 other regulatory agencies will impose 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. As of December 31, 2020, SCE recorded $8 million of estimated minimum liability in relation to the Mission Canyon Incident, primarily associated with environmental remediation. Costs incurred for the year ended December 31, 2020 Mission Canyon Incident was approximately $7 million. SCE will not seek recovery of these costs from customers in rates.

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 $122 million and $8 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. The ultimate costs to remediate the Mission Canyon Incident is currently not estimable.

SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next 5 years are expected to range from $9 million to $20 million. Costs incurred for years ended December 31, 2020, 2019 and 2018 were $7 million, $9 million and $8 million, respectively.

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 $13.8 billion for Palo Verde and $560 million for San Onofre. As of January 1, 2020, SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available ($450 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

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maintains an ANI Master Worker Form policy that provides coverage for non-licensee workers. This program provides a shared industry aggregate limit of $450 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 minor 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 $65 million per nuclear incident for future incidents. However, it would have to pay no more than approximately $10 million per future incident in any one year. 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 $30 million per year. Insurance premiums are charged to operating expense.

Spent Nuclear Fuel

Under federal law, the 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. Currently, both San Onofre and Palo Verde have interim storage for spent nuclear fuel on site sufficient for their current license period.

In June 2010, the United States Court of Federal Claims issued a decision granting SCE and the San Onofre co-owners damages of approximately $142 million (SCE share $112 million) to recover costs incurred through December 31, 2005 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. SCE received payment from the federal government in the amount of the damage award. In April 2016, SCE, as operating agent, settled a lawsuit on behalf of the San Onofre owners against the DOE for $162 million (SCE share $124 million, which included reimbursement for approximately $2 million in legal and other costs), to compensate for damages caused by the DOE's failure to meet its obligation to begin accepting spent nuclear fuel for the period from January 1, 2006 to December 31, 2013. In August 2018, the CPUC approved SCE's proposal to return the SCE share of the award to customers based on the amount that customers actually contributed for fuel storage costs; resulting in approximately $106 million of the SCE share being returned to customers and the remaining $17 million being returned to shareholders. Of the $106 million, $72 million was applied against the remaining San Onofre Regulatory Asset in accordance with the Revised San Onofre Settlement Agreement.

The April 2016 settlement also provided for a claim submission/audit process for expenses incurred from 2014 – 2016, where SCE may submit a claim for damages caused by the DOE failure to accept spent nuclear fuel each year, followed by a government audit and payment of the claim. This process made additional legal action to recover damages incurred in 2014 – 2016 unnecessary. The first such claim covering damages for 2014 – 2015 was filed on September 30, 2016 for approximately $56 million. In February 2017, the DOE reviewed the 2014 – 2015 claim submission and reduced the original request to approximately $43 million (SCE share was approximately $34 million). SCE accepted the DOE's determination, and the government paid the 2014 – 2015 claim under the terms of the settlement. In October 2017, SCE filed a claim covering damages for 2016 for approximately $58 million. In May 2018, the DOE approved reimbursement of approximately $45 million (SCE share was approximately $35 million) of SCE's 2016 damages, disallowing recovery of approximately $13 million. SCE accepted the DOE's determination, and the government paid the 2016 claim under the terms of the settlement. The damages awards are subject to CPUC review as to how the amounts will be refunded among customers, shareholders, or to offset other costs.

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In November 2019, SCE filed a new complaint against the DOE to recover damages incurred from January 1, 2017 through July 31, 2018.

Upstream Lighting Program

From 2017 – 2019, SCE administered the Upstream Lighting Program, part of a statewide program administered by investor-owned utilities that offered discounted energy efficient light bulbs to customers through incentives to lighting manufacturers. The CPUC began investigating the programs administered by the investor-owned utilities based on reports that investor-owned utilities, including SCE, shipped a significant number of bulbs under the program that could not be tracked to customers. Beginning in January 2020, the CPUC has sought comments on remedies related to SCE's implementation of the Upstream Lighting Program from 2017 through 2019 program years. SCE undertook an independent investigation of bulbs shipped to retailers categorized as grocery and discount businesses during the 2017 to 2019 program years and found that there were overstocking of bulbs and program management shortcomings. Incentives paid to manufacturers for bulbs shipped to grocery and discount businesses during the relevant period, including those that were sold to customers, were approximately $91 million. In addition, SCE received incentives related to the bulbs shipped to grocery and discount businesses through an energy efficiency incentive mechanism ("ESPI Mechanism") of approximately $3.5 million related to the bulbs shipped in 2017 and 2018. SCE also expects to receive incentives of approximately $1.3 million under the ESPI Mechanism in 2022 related to bulbs shipped to grocery and discount businesses in 2018 and 2019. In January 2021, the Public Advocates Office and The Utility Reform Network provided comments to the CPUC arguing that SCE imprudently managed the program and requesting: a refund of $33 million of ESPI awards, which includes incentives associated with the Upstream Lighting Program and other energy efficiency programs; a refund of $92 million of incentives paid to manufacturers and associated program administrative costs; $140 million in fines; and additional program improvements to be provided at shareholder expense. SCE has accrued a charge for potential losses relating to the Upstream Lighting Program. The accrued charge corresponds to the lower end of the reasonably estimated range of expected losses that may be incurred in connection with the Upstream Lighting Program and is subject to change as additional information becomes available.

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 contracts included in the table below are primarily 3 to 20 years for PPA leases, 5 to 72 years for office leases, and 5 to 13 years for the remaining other operating leases.

The following table summarizes SCE's lease payments for operating and finance leases as of December 31, 2020:

(in millions)			PPA Operating Leases1						Other Operating Leases2						PPA Finance Leases1
2021			$	204					$	39					$	1
2022			208						32						1
2023			159						26						1
2024			47						21						—
2025			47						18						—
Thereafter			443						104						5
Total lease payments			1,108						240						8
Amount representing interest3			203						60						4
Lease liabilities			$	905					$	180					$	4

1Excludes expected purchases from most renewable energy contracts, which do not meet the definition of a lease payment since renewable power generation is contingent on external factors.

2Excludes 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.

3Lease payments are discounted to their present value using SCE's incremental borrowing rates.

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Supplemental balance sheet information related to SCE's leases was as follows:

(in millions)			December 31, 2020						December 31, 2019
Operating leases:
Operating lease ROU assets1			$	1,085					$	689
Current portion of operating lease liabilities			214						79
Operating lease liabilities			871						610
Total operating lease liabilities1			$	1,085					$	689
Finance leases included in:
Utility property, plant and equipment, gross			$	4					$	14
Accumulated depreciation			—						(5)
Utility property, plant and equipment, net			4						9
Other current liabilities			—						1
Other long-term liabilities			4						8
Total finance lease liabilities			$	4					$	9

1During the year ended 2020, a PPA operating lease commenced and one PPA was amended resulting in a total of $463 million additions in ROU assets and lease liabilities.

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 operating leases and interest and amortization expense for finance leases. The following table summarizes the components of SCE's lease expense:

(in millions)			Year ended December 31, 2020						Year ended December 31, 2019
PPA leases:
Operating lease cost			$	111					$	118
Finance lease cost			1						1
Variable lease cost1			1,917						2,087
Total PPA lease cost			2,029						2,206
Other operating leases cost			47						46
Total lease cost			$	2,076					$	2,252

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

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Other information related to leases was as follows:

(in millions, except lease term and discount rate)			Year ended December 31, 2020						Year ended December 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases
PPA leases			$	111					$	118
Other leases			44						44
Financing cash flows from PPA finance leases			1						1
ROU assets obtained in exchange for lease obligations:
PPA operating leases			$	463					—
Other operating leases			58						34
Weighted average remaining lease term (in years):
Operating leases
PPA leases			9.75						16.05
Other leases			12.13						12.73
PPA Finance leases			16.67						11.51
Weighted average discount rate:
Operating leases
PPA leases			3.12		%				4.46		%
Other leases			3.63		%				3.88		%
PPA Finance leases			11.29		%				8.76		%

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 twelve months ended December 31, 2020 and December 31, 2019, SCE recognized $17 million and $18 million, respectively, in lease income, which is included in operating revenue on the consolidated statements of income. At December 31, 2020, the undiscounted cash flow expected to be received from lease payments for the remaining years is as follows:

(in millions)
2021			$	11
2022			10
2023			8
2024			7
2025			6
Thereafter			128
Total			$	170

EME, a wholly-owned subsidiary of Edison International, emerged from bankruptcy in 2014 and retained a lease investment in a hydroelectric power plant in Vidalia, Louisiana. In November 2020, the lessee exercised an option in the lease agreement and purchased the asset upon expiration of the lease term. Edison International recognized the net proceeds of $132 million as a pre-tax gain and has no remaining investment balance as of December 31, 2020 related to the lease investment. The revenue recognized for the lease in 2020 is immaterial to Edison International's consolidated financial statements.

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Note 14.    Equity

Common Stock Issuances

In May 2020, Edison International issued 14,181,882 shares of common stock in a registered direct offering and received approximately $800 million in proceeds, before deducting fees and offering expenses of $14 million. The proceeds were used to pay off debt outstanding under a term loan agreement and for general corporate purposes. Refer to Note 5 for details of the term loan.

In May 2019, Edison International filed a prospectus supplement and executed several distribution agreements with certain sales agents to establish an "at-the-market" ("ATM") program under which it may sell shares of its common stock having an aggregate sales price of up to $1.5 billion. During the three months ended December 31, 2020, Edison International did not issue any shares through the ATM program. During the twelve months ended December 31, 2020, Edison International issued 391,501 shares through the ATM program and received proceeds of $27 million, net of fees and offering expenses of $0.3 million. During the three and twelve months ended December 31, 2019, Edison International issued 2,824,261 shares through the ATM program and received proceeds of $198 million, net of fees and offering expenses of $2 million. The proceeds from the sales were used for equity contributions to SCE and for general corporate and working capital purposes. As of December 31, 2020, shares of common stock having an aggregate offering price of $1.3 billion remained available to be sold under the ATM program. Edison International has no obligation to sell the remaining available shares.

Edison International continued to settle its ongoing common stock requirements of various internal programs through issuance of new common stock. During the twelve months ended December 31, 2020, 1,644,500 shares of common stock were purchased by employees through the 401(k) defined contribution savings plan for net cash receipts of $99 million, 387,425 shares of common stock were issued as stock compensation awards for net cash receipts of $16 million, 280,707 shares of new common stock were issued in lieu of distributing $17 million to shareholders opting to receive dividend payments in the form of additional common stock and 35,999 shares of common stock related to optional cash investments of $2 million.

During the twelve months ended December 31, 2019, 595,200 shares of common stock were purchased by employees through the 401(k) defined contribution savings plan for net cash receipts of $41 million, 423,569 shares of common stock were issued as stock compensation awards for net cash receipts of $22 million and 125,481 shares of new common stock were issued in lieu of distributing $8 million to shareholders opting to receive dividend payments in the form of additional common stock. Edison International did not have optional cash investment issuances in December 31, 2019.

Equity Contributions

In 2020, Edison International Parent made the following equity contributions to SCE:

Date of contribution			Amounts (in millions)
February 28, 2020			$	269
April 29, 2020			200
May 26, 2020			319
June 30, 2020			100
August 31, 2020			219
December 18, 2020			325
Total			$	1,432

The proceeds from the Edison International Parent equity contributions in 2020 were used to support SCE's capital program, maintain the equity portion of SCE's capital structure at authorized levels and for general corporate purposes.

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 are no dividends in arrears for the preferred or preference shares.

During the third quarter of 2020, SCE redeemed $120 million of cumulative preferred stock consisting of all of the outstanding shares of the 4.32% Series, 4.08% Series, 4.24% Series and the 4.78% Series at a price of $28.75, $25.50, $25.80 and $25.80, respectively. SCE recorded a $9 million loss on the redemption of the preferred stock as an adjustment to net

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income available to common stockholders. No preferred shares were issued or redeemed in the years ended December 31, 2019 and 2018. There is no sinking fund requirement for redemptions or repurchases of preferred shares.

Shares of SCE's preference stock rank senior to all common stock. Shares of SCE's preference stock are not convertible into shares of any other class or series of SCE's capital stock or any other security. 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.

Preferred stock and preference stock are:

			Shares Outstanding						Redemption Price						Dividends Declared per Share						December 31,
(in millions, except shares and per share amounts)																					2020						2019
Cumulative preferred stock
$25 par value:
4.08% Series			—						$	25.50					$	0.757					$	—					$	16
4.24% Series			—						25.80						0.786						—						30
4.32% Series			—						28.75						0.801						—						41
4.78% Series			—						25.80						0.886						—						33
Preference stock
No par value:
6.25% Series E (cumulative)			350,000						1,000.00						62.500						350						350
5.10% Series G (cumulative)			88,004						2,500.00						127.500						220						400
5.75% Series H (cumulative)			110,004						2,500.00						143.750						275						275
5.375% Series J (cumulative)			130,004						2,500.00						134.375						325						325
5.45% Series K (cumulative)			120,004						2,500.00						136.250						300						300
5.00% Series L (cumulative)			190,004						2,500.00						125.000						475						475
SCE's preferred and preference stock																					1,945						2,245
Less issuance costs																					(44)						(52)
Edison International's preferred and preference stock of utility																					$	1,901					$	2,193

Shares of Series E preference stock issued in 2012 may be redeemed at par, in whole or in part, on or after February 1, 2022. Shares of Series G, H, J, K and L preference stock, issued in 2013, 2014, 2015, 2016 and 2017, respectively, may be redeemed at par, in whole, but not in part, at any time prior to March 15, 2018, March 15, 2024, September 15, 2025, March 15, 2026 and June 26, 2022, respectively, if certain changes in tax or investment company law or interpretation (or applicable rating agency equity credit criteria for Series L only) occur and certain other conditions are satisfied. On or after March 15, 2018, March 15, 2024, September 15, 2025, March 15, 2026 and June 26, 2022, SCE may redeem the Series G, H, J, K and L shares, respectively, at par, in whole or in part. For shares of Series H, J and K preference stock, distributions will accrue and be payable at a floating rate from and including March 15, 2024, September 15, 2025 and March 15, 2026, respectively. Shares of Series G, H, J, K and L preference stock were issued to SCE Trust II, SCE Trust III, SCE Trust IV, SCE Trust V and SCE Trust VI, respectively, special purpose entities formed to issue trust securities as discussed in Note 3. During the third quarter of 2020, SCE redeemed $180 million of the outstanding shares of the Series G preference stock. SCE recorded a $6 million loss on the redemption of the preference stock as an adjustment to net income available to common stockholders. No preference shares were issued or redeemed in the years ended December 31, 2019 and 2018.

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Note 15.    Accumulated Other Comprehensive Loss

The changes in accumulated other comprehensive loss, net of tax, consist of:

			Edison International												SCE
			Years ended December 31,
(in millions)			2020						2019						2020						2019
Beginning balance			$	(69)					$	(50)					$	(39)					$	(23)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications			(8)						(14)						(7)						(14)
Reclassified from accumulated other comprehensive loss1			8						5						5						3
Other2			—						(10)						—						(5)
Change			—						(19)						(2)						(16)
Ending balance			$	(69)					$	(69)					$	(41)					$	(39)

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

2    Edison International and SCE recognized cumulative effect adjustments to the opening balance of retained earnings and accumulated other comprehensive loss on January 1, 2019 related to the adoption of the accounting standards update on the reclassification of stranded tax effects resulting from Tax Reform in 2019.

Note 16.    Other Income

Other income net of expenses is as follows:

						Years ended December 31,
(in millions)						2020						2019						2018
SCE other income and (expenses):
Equity allowance for funds used during construction						$	121					$	101					$	104
Increase in cash surrender value of life insurance policies and life insurance benefits						66						39						36
Interest income						20						37						24
Net periodic benefit income – non-service components						102						70						81
Civic, political and related activities and donations						(42)						(46)						(44)
Other						(12)						(6)						(7)
Total SCE other income						255						195						194
Other income of Edison International Parent and Other:
Net periodic benefit costs – non-service components						(2)						(3)						(2)
Other						(2)						1						5
Total Edison International other income						$	251					$	193					$	197

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Note 17.    Supplemental Cash Flows Information

Supplemental cash flows information is:

			Edison International																		SCE
			Years ended December 31,
(in millions)			2020						2019						2018						2020						2019						2018
Cash payments (receipts):
Interest, net of amounts capitalized			$	836					$	705					$	595					$	713					$	615					$	552
Income taxes, net			(34)						(85)						(135)						(50)						(164)						(57)
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock			251						231						200						—						200						—
Preferred and preference stock			11						12						12						11						12						12

SCE's accrued capital expenditures at December 31, 2020, 2019 and 2018 were $730 million, $643 million and $594 million, respectively. Accrued capital expenditures will be included as an investing activity 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 good 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, 2020, 2019 and 2018, SCE purchased wildfire liability insurance for premiums of $176 million, $260 million and $22 million respectively, from Edison Insurance Services, Inc. ("EIS"), a wholly-owned subsidiary of Edison International. 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. The related-party transactions included in SCE's consolidated balance sheets for wildfire-related insurance purchased from EIS and related expected insurance recoveries were as follows:

						December 31,
(in millions)						2020						2019
Current insurance receivable due from affiliate						$	268					$	—
Long-term insurance receivables due from affiliate						—						803
Prepaid insurance1						56						10

1 Reflected in "Prepaid expenses" on SCE's consolidated balance sheets.

The expense for wildfire-related insurance premiums paid to EIS were $189 million, $173 million and $140 million for the years ended December 31, 2020, 2019 and 2018 respectively.

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Note 19.    Quarterly Financial Data (Unaudited)

Edison International's quarterly financial data is as follows:

			2020
(in millions, except per share amounts)						Fourth						Third						Second						First
Operating revenue						$	3,157					$	4,644					$	2,987					$	2,790
Operating income (loss)						794						(379)						500						302
Net income (loss)						552						(242)						348						213
Net income (loss) attributable to common shareholders						526						(288)						318						183
Basic earnings (loss) per share:						$	1.39					$	(0.76)					$	0.85					$	0.50
Diluted earnings (loss) per share:						$	1.39					$	(0.76)					$	0.85					$	0.50
Dividends declared per share						0.6625						0.6375						0.6375						0.6375

			2019
(in millions, except per share amounts)						Fourth						Third						Second						First
Operating revenue						$	2,970					$	3,741					$	2,812					$	2,824
Operating income						287						636						500						352
Net income						173						502						422						308
Net income attributable to common shareholders						143						471						392						278
Basic earnings per share:						$	0.40					$	1.36					$	1.20					$	0.85
Diluted earnings per share:						$	0.40					$	1.35					$	1.20					$	0.85
Dividends declared per share						0.6375						0.6125						0.6125						0.6125

SCE's quarterly financial data is as follows:

			2020
(in millions)						Fourth						Third						Second						First
Operating revenue						$	3,151					$	4,635					$	2,980					$	2,780
Operating income (loss)						678						(364)						548						316
Net income (loss)						500						(218)						411						249
Net income (loss) available for common stock						474						(264)						381						219
Common dividends declared						325						269						269						269

			2019
(in millions)						Fourth						Third						Second						First
Operating revenue						$	2,958					$	3,732					$	2,800					$	2,816
Operating income						325						649						513						358
Net income						224						534						449						323
Net income available for common stock						194						503						419						293
Common dividends declared						200						200						—						200

Due to the seasonal nature of Edison International and SCE's business, a significant amount of revenue and earnings are recorded in the third quarter of each year.

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SELECTED FINANCIAL DATA

Selected Financial Data: 2016 – 2020

(in millions, except per share amounts)			2020						2019						2018						2017						2016
Edison International
Operating revenue1			$	13,578					$	12,347					$	12,657					$	12,320					$	11,869
Operating expenses2			12,361						10,572						13,209						10,864						9,807
Income (loss) from continuing operations			871						1,405						(350)						668						1,413
Income from discontinued operations, net of tax			—						—						34						—						12
Net income (loss)			871						1,405						(316)						668						1,425
Net income (loss) attributable to common shareholders			739						1,284						(423)						565						1,311
Weighted average shares of common stock outstanding			373						340						326						326						326
Basic earnings (loss) per share:
Continuing operations			$	1.98					$	3.78					$	(1.40)					$	1.73					$	3.99
Discontinued operations			—						—						0.10						—						0.03
Total			$	1.98					$	3.78					$	(1.30)					$	1.73					$	4.02
Diluted earnings (loss) per share:
Continuing operations			$	1.98					$	3.77					$	(1.40)					$	1.72					$	3.94
Discontinued operations			—						—						0.10						—						0.03
Total			$	1.98					$	3.77					$	(1.30)					$	1.72					$	3.97
Dividends declared per share			2.5750						2.4750						2.4275						2.2325						1.9825
Total assets3, 4			$	69,372					$	64,382					$	56,715					$	52,580					$	51,319
Long-term debt excluding current portion			19,632						17,864						14,632						11,642						10,175
Preferred and preference stock of utility			1,901						2,193						2,193						2,193						2,191
Common shareholders' equity			14,048						13,303						10,459						11,671						11,996
Southern California Edison Company
Operating revenue1			$	13,546					$	12,306					$	12,611					$	12,254					$	11,830
Operating expenses2			12,368						10,461						13,017						10,707						9,648
Net income (loss)			942						1,530						(189)						1,136						1,499
Net income (loss) available for common stock			810						1,409						(310)						1,012						1,376
Total assets			$	69,286					$	64,273					$	56,574					$	51,515					$	50,891
Long-term debt excluding current portion			16,499						15,132						12,892						10,428						9,754
Preferred and preference stock			1,945						2,245						2,245						2,245						2,245
Common shareholder's equity			16,705						15,582						11,540						12,427						12,238
Capital structure4:
Common shareholder's equity			47.5		%				47.3		%				43.3		%				49.5		%				50.5		%
Preferred and preference stock			5.5		%				6.8		%				8.4		%				9.0		%				9.3		%
Long-term debt			46.9		%				45.9		%				48.3		%				41.5		%				40.2		%

1    Effective January 1, 2018, Edison International and SCE adopted an accounting standards update on revenue recognition, using the modified retrospective method. As a result, prior period amounts were not adjusted to reflect the adoption of this standard.

2     Expenses for the years ended December 31, 2017 and 2016 were updated to reflect the implementation of the accounting standard update for net periodic benefit costs related to the defined benefit pension and other postretirement plans.

3 Includes assets from continuing and discontinued operations.

4     This capital structure is based on the financial statements as reported under generally accepted accounting principles and does not factor in the adjustments required to calculate CPUC ratemaking capital structure.

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The selected financial data was derived from Edison International's and SCE's audited financial statements and is qualified in its entirety by the more detailed information and financial statements, including notes to those financial statements, included in this annual report. References to Edison International refer to the consolidated group of Edison International and its subsidiaries.

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, 2020, 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, 2020. Edison International's internal control over financial reporting as of December 31, 2020 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report on the financial statements included in this report, 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 2020 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.

OTHER INFORMATION

None.

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

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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 Edison Energy which is engaged in the competitive business of providing data-driven energy solutions to commercial, institutional and industrial customers.

The principal executive offices of Edison International and SCE are located at 2244 Walnut Grove Avenue, P.O. Box 976, Rosemead, California 91770, and the telephone numbers are (626) 302-2222 for Edison International and (626) 302-1212 for SCE.

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. SCE's total number of customers by class were as follows:

(in thousands)						2020						2019						2018
Residential						4,531						4,499						4,478
Commercial						577						575						572
Industrial						9						10						10
Public authorities						46						46						46
Agricultural and other						20						21						21
Total						5,183						5,151						5,127

In 2020, SCE's total operating revenue of $13.5 billion was derived as follows: 42.4% residential customers, 40.1% commercial customers, 3.7% industrial customers, 3.9% public authorities, 3.6% agricultural and other, and 6.3% other operating revenue.

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 to customers does not have a direct impact on SCE's financial results. See "SCE—Overview of Ratemaking Process—CPUC" and "—FERC" for further information.

Edison Energy Group – Energy Service Provider

Edison Energy Group is a holding company for Edison Energy which is engaged in the competitive business of providing data-driven energy solutions to commercial, institutional and industrial customers. Edison Energy aims to provide energy solutions that address cost, carbon and complex choices for their customers. In April 2018, Edison Energy Group sold its subsidiary SoCore Energy, which was engaged in providing distributed solar solutions.

To date, investments in Edison Energy Group are below 1% of the total consolidated assets and operating revenue, and therefore are not material to be reported as a business segment.

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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 SCE's 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, 2020, Edison International had an aggregate of 13,351 employees (excluding interns and employees on a leaves of absence), of which 13,067 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 SCE's non-employee workers are 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 ("Safety Tier 1 Contractors"). SCE estimates, based on contractors' self-reported hours worked and a 2,080-hour work year, that there were approximately 11,000 full-time equivalent Safety Tier 1 Contractors supporting SCE operations during 2020. SCE also uses other contract workers to support its transmission and distribution, vegetation management, information technology and customer service activities.

Approximately 4,000 of SCE's employees are covered by collective bargaining agreements with the International Brotherhood of Electrical Workers ("IBEW"). The IBEW collective bargaining agreements expire on December 31, 2022. In addition, 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 creating and maintaining a safe environment for its employees, contract workers, customers and the public. Over the past several years, Edison International’s efforts to improve workforce safety have included increased focus on, and investment in, developing 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 makes efforts to eliminate fatalities and serious injuries and reduce all injuries. For instance, 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. In addition, SCE implemented more safety requirements for both prime contractors and subcontractors in 2020.

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Edison International uses employee safety culture assessments to measure its progress relative to improving employee safety. 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 2020:

Employee work-related fatalities			0
Employee EEI Serious Injuries			17
Employee EEI SIF Rate1			0.12
Employee DART Rate2			0.89
Safety Tier 1 Contractor work-related fatalities			3
Safety Tier 1 Contractor EEI Serious Injuries			18
Safety Tier 1 Contractor DART Rate2			0.45

1     Employee EEI SIF Rate is calculated by multiplying the total number of employee EEI SIFs by 200,000 and then dividing by the total number of reported hours worked by all employees.

2    DART Rate is calculated by multiplying the number of DARTs by 200,000 and then dividing by the total number of reported hours worked.

In response to the COVID-19 pandemic, Edison International has looked for ways to minimize exposure risk and protect the health and safety of its employees. All Edison International employees who, in the company’s assessment, can work remotely and perform their job functions effectively have been directed to do so. Approximately two-thirds of Edison International's employees were working remotely as of February 1, 2021. In addition, Edison International has taken additional steps to minimize exposure for those employees who are not working remotely, including modified work practices and more frequent and enhanced cleanings at staffed facilities. Edison International has also extended several benefits to help all employees during the pandemic, including providing additional paid leave related to the pandemic for illness, quarantine or to care for family members.

Diversity, Equity and Inclusion

Edison International is committed to developing a team that reflects the broad diversity of the customers and communities it serves. At Edison International, on average, employees in the same role get equal pay for equal work. Similar to broader society, when looking at gender or race/ethnicity-specific groups across the company, female, Black and Hispanic employees at Edison International are paid less due to lower representation in higher paying jobs. Edison International is committed to working towards increasing diversity in its higher paying jobs.

The table below Edison International's employee diversity data1 as of December 31, 2020:

			Employees2			Leaders3			Executives4
Females			32		%	26		%	37		%
Racially/ethnically diverse			61		%	49		%	34		%
Racially/ethnically or gender diverse			70		%	60		%	59		%

1     Calculated using the guidelines SCE uses to calculate the diversity data it reports to the United States Equal Employment Opportunity Commission.

2      Excludes interns and employees on a leave of absence.

3     "Leaders" represents all principal manager, senior manager, manager, senior supervisor and supervisor level employees.

4     "Executives" represents all officers and all director level employees.

To support Edison International's diversity, equity and inclusion efforts, Executives and Leaders are offered the training and tools to promote diverse representation throughout their teams. In addition, Edison International evaluates whether hiring processes include diverse candidates and diverse sets of decision makers. In addition to measuring diversity, Edison International also uses various other measures to assess success of diversity, equity and inclusion initiatives, including without limitation, monitoring hiring, promotion and turnover rates for diverse employees.

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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 provided with training opportunities, including an onboarding program, technical training, required ethics and compliance training and optional trainings to support career development.

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 sentiment surveys and monitoring turnover. Edison International Parent and SCE's combined Turnover Rate for 2020 and 2019 were 5.1% and 5.6%, respectively.

Executives engage in succession planning for leadership positions within the organization. Edison International's and SCE's Boards of Directors also engage in annual succession planning and talent development discussions for senior officers.

Edison International's Diversity, Equity and Inclusion Report and Sustainability Report are available at http://www.edison.com/sustainability. The reports 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. 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.

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

Major transmission projects required for reliability and accessing renewable resources are recommended by the CAISO through a regular transmission planning process that highlights the need for and key issues associated with each project. Much of SCE's transmission investment program has been for transmission projects that facilitated access to renewable energy resources in desert and mountain regions east and north of its load center to meet the 33% renewable mandate by December 2020. The CAISO will similarly be initiating long-term transmission planning for 50% of SCE's retail electricity to be from qualifying renewable resources by 2030 and is conducting informational studies on achieving higher percentages from qualifying renewable resources.

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 cyber

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security assets, including supervisory control and data acquisition systems for the electric grid. Compliance with these standards is mandatory. The maximum penalty that may be levied for violating a NERC reliability or critical infrastructure protection standard is $1 million per violation, per day.

SCE has a formal cyber security and physical security programs that cover SCE's information technology and operational technology systems, including customer data. Program staff is engaged with industry groups as well as public-private initiatives to reduce risk and to strengthen the security and reliability of SCE's systems and infrastructure.

Nuclear Power Plant Regulation

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. 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 the 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 CAISO, the US EPA, 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 Game, and the California Coastal Commission; the South Coast Air Quality Management District; and the California Water Quality 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, including 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 SONGS; 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. There is no assurance that SCE will be allowed to recover these costs. For further information on wildfire mitigation and wildfire insurance costs, see "Management Overview—Wildfire Mitigation, Wildfire Insurance and Restoration Expenses" in the MD&A.

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. Starting with SCE's 2021 GRC, revenue will be 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. Beginning with SCE's 2025 GRC, 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

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CPUC to provide information about SCE's assessment of its key safety risks and its proposed programs and spending for mitigating those risks. The information developed during the RAMP informs SCE's proposed projects and funding requests in the subsequent phase of the GRC.

SCE's 2018 GRC, a triennial proceeding, authorized revenue requirements for 2018, 2019 and 2020 were $5.1 billion, $5.5 billion and $5.9 billion, respectively.

SCE's first RAMP application was timely filed in November 2018 for its 2021 GRC. In August 2019, SCE filed its 2021 GRC Application, which covered 2021 – 2023 in addition to a review of wildfire mitigation spending incremental to amounts authorized in SCE's 2018 GRC incurred from 2018 – 2020. SCE will make additional filings the 2021 GRC proceeding to cover 2024. For further discussion of the 2021 GRC, see "Management Overview—2021 GRC" in the MD&A.

The CPUC regulates SCE's cost of capital, including its capital structure and authorized rates of return. As of January 1, 2020, SCE's authorized capital structure is 43% long-term debt, 5% preferred equity and 52% common equity. SCE's authorized cost of capital for 2020, 2021 and 2022 consists of: cost of long-term debt of 4.74%, cost of preferred equity of 5.70% and ROE of 10.3%. A cost of capital mechanism set by the CPUC could adjust authorized cost of capital between SCE's cost of capital proceedings. The benchmark value for the current mechanism is the 12-month, October 1, 2018 through September 30, 2019, average Moody's Baa utility bond yield of 4.5%. If the difference between the benchmark and the average of the same index for the 12-month period to September 30, 2021 exceeds 100-basis points, SCE's CPUC-authorized ROE will be adjusted for 2022 by half the amount of the difference (up or down). If the mechanism is triggered SCE’s costs of long-term debt and preferred equity will also be adjusted for 2022 to reflect the then current embedded costs and projected interest rates. SCE is required to file its next cost of capital application by April 2022 for rates effective beginning January 2023.

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 volumetric related to retail electricity sales.

Cost-recovery balancing accounts (also referred to as cost-recovery mechanisms) are used to track and recover SCE's decoupled costs of fuel and purchased power, as well as certain operation and maintenance expenses, including energy efficiency and demand-side management program costs. 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 has other capital-related balancing accounts on which it earns a return, such as the pole loading balancing account.

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 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 2021, SCE estimates the 4% and 5% trigger amounts to be approximately $205 million and $256 million, respectively. At December 31, 2020, the ERRA was overcollected by approximately $148 million, the PABA was undercollected by approximately $435 million, and the NSGBA was overcollected by approximately $10 million. SCE began incorporating these year-end balances into customer rates in February 2021.

The majority of 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.

FERC

Transmission capital and operating costs that are prudently incurred, including a return on its net investment in transmission assets (also referred to as "rate base"), 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

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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 weighted average ROE, including project and other incentives, for the FERC 2019 Settlement Period is 10.3%. For further information on the FERC formula rates, related transmission revenue requirements and rate changes, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings—2019 FERC Formula Rate" 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 with a separate High Usage Charge ("HUC") for customers consuming more than 400% of an established level of usage that is based on a portion of average usage. The first tier is priced at below-average cost and is intended to cover the customer's essential electricity needs. The second tier is priced at 25% more than the first tier, and the HUC rate is ordinarily set at 75% more than the second tier. In response to Governor Newsom’s Executive Order N-33-20 directing Californians to follow state health directives to stay home, however, the CPUC ordered SCE, starting in June 2020, to temporarily reduce the HUC rate such that is set at 25% more than the second tier. This temporary adjustment to the HUC rate will stay in effect until SCE receives a letter from the CPUC’s Executive Director instructing it to return the HUC rate to its original level. There is an ongoing proceeding before the CPUC in which modification and/or elimination of the HUC is being considered. The CPUC has ordered a transition from tiered to time-of-use rates for most residential customers unless they opt to stay on the tiered rate structure. SCE started that transition in the fourth quarter of 2020 and anticipates completing the transition in the first quarter of 2022. 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). 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. Approximately 17% of the needed power in 2020 was provided by SCE's own generating facilities.

Natural Gas Supply

SCE requires natural gas to meet contractual obligations for power tolling agreements (power contracts in which SCE has agreed to provide or pay for the natural gas used to generate electricity). SCE also 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 and at the "citygate" trading point 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. As a result, there continue to be limitations on the use and capability of the facility, and the current available inventory at the Aliso Canyon facility is limited to 50% of maximum capacity. To date, SCE has found that increased gas storage-use restrictions combined with SoCalGas pipeline maintenance constraints increased the cost of electricity 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, contracting for firm gas transportation capacity and procuring additional energy efficiency.

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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 six neighboring states through the 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 purchases for its load requirements.

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, starting with the 2023 resource adequacy compliance year. Under this structure, while SCE will procure 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 rotating outages in August 2020 that impacted a significant number of SCE's customers, the CPUC opened an emergency rulemaking proceeding to take action towards ensuring reliable electric service in the event that an extreme heat event occurs in the summer of 2021. In February 2021, the CPUC issued a final decision directing the investor-owned utilities to seek contracts for capacity to serve demand in the summer of 2021. As required by the decision, SCE has submitted contracts to purchase additional capacity in the summer of 2021 for CPUC approval. The CPUC is also considering other options to enhance reliability for summer 2021, including proposals related to the demand for electricity during extreme heat events. In addition, the CAISO is also taking actions to help ensure reliability in the summer of 2021.

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 generally impact SCE's earnings activities. 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 previously took 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 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 is conducting a rulemaking proceeding to review and revise the PCIA methodology, which determines the charges that are applied to departing load customers (including those who take service from CCAs) and is intended to maintain bundled service customer indifference to departing load for costs of previously authorized procurement resources. In October 2018, the CPUC issued a final decision revising the PCIA methodology in a manner that effectively addressed the cost shifts to remaining bundled service customers. In October 2019, the CPUC issued a final decision implementing a PCIA true-up process to ensure that remaining bundled service and departing load customers are treated equitably. In August 2020, the CPUC issued a final decision implementing a process that will voluntarily allow Direct Access customers and CCAs on behalf of their retail customers to negotiate with SCE to pre-pay their full PCIA obligation. The CPUC is expected to provide guidance on utility portfolio optimization to account for departing load in 2021.

In February 2018, the CPUC issued a resolution to address cost shifting to bundled service customers associated with utilities' short-term resource adequacy purchases for CCAs in their launch or expansion year. The Resolution requires new and expanding CCAs to submit implementation plans by January 1 in order to serve customers in the following year and also requires new and expanding CCAs to participate in the CPUC's year-ahead resource adequacy program prior to beginning service. In May 2018, the CPUC issued a final decision to adopt a financial security requirement for CCAs, which is intended

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to cover the re-entry fees imposed on CCA customers for incremental procurement and administrative costs if they are involuntarily returned en masse to the utility's procurement service. In October 2020, the CPUC authorized SCE and other investor-owned utilities to implement this decision in its tariffs.

As of year-end 2020, SCE had ten CCAs serving customers in its service territory that represented approximately 25% of SCE's total service load. Four new CCAs implemented and one CCA expanded in SCE's service territory in 2020. Four new or expanded CCAs have been approved by the CPUC to serve customers in 2021. Based on recent load statistics, SCE anticipates that Direct Access and CCA load will be approximately 40% of its total service load by the end of 2021.

Customer-owned power generation and storage alternatives, such as roof-top solar facilities and battery systems, are increasingly used by SCE's customers as a result of technological developments, federal and state subsidies, and declining costs of such alternatives. Beginning in 2020, and subject to certain exceptions, all newly built homes in California are required to be solar-powered.

California legislation passed in 1995 encouraged private residential and commercial investment in renewable energy resources by requiring SCE and other investor-owned 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 are not required by law to offer NEM rates.

In January 2016, the CPUC issued a decision implementing Assembly Bill 327 ("AB 327"), a rate reform bill enacted in 2013 that instructed the CPUC to develop new standard rates for customers with renewable generation systems. The changes that the CPUC decision made to the existing NEM tariff do not significantly impact the NEM subsidy. Specifically, the decision requires 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 continue to be exempted from standby and departing load charges but are 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 the CPUC created in its January 2016 decision implementing AB 327. The CPUC expects to issue its decision in the proceeding in 2021.

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 utilize and pay for SCE's transmission and distribution services, however, NEM customers utilize, 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. 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 substations. SCE's distribution system, which takes power from substations to customers, consists of approximately 39,000 circuit-miles of overhead lines, approximately 31,000 circuit-miles of underground lines and substations, all of which are located in California. Substantially all of SCE's approximately 800 substations are located in California. SCE has ownership interests in generating and energy storage facilities, primarily located in California, that generate approximately 7,000 megawatts of net physical capacity, of which SCE's pro-rata share is approximately 3,000 megawatts. SCE's pro rata share includes approximately 830 megawatts of capacity from SCE's hydroelectric facilities in Big Creek, California, where damage caused by the Creek Fire in 2020 has significantly impacted operations and generation capacity of the Big Creek facilities. The Big Creek facilities are not expected to be fully operational until at least the fourth quarter of 2021.

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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 between 2021 and 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. SCE has requested starting recovery of a portion of estimated of decommissioning costs for hydroelectric projects in the 2021 GRC.

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.

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 customers of the electric grid. See "Management Overview—Electricity Industry Trends" in the MD&A.

Approximately 17% of power delivered to SCE's customers in 2020 came from utility-owned generation. In 2020, the sources of utility-owned generation were largely carbon-free, with approximately 8% nuclear, 3% 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 US EPA by March 31 of the following year. SCE's 2020 GHG emissions from utility-owned generation are estimated to be approximately 1,200,000 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, an Executive Order that targets the reduction of GHG emissions across the entire state economy to 80% below 1990 levels by 2050, 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 the California cap-and-trade program, all covered GHG emitters, including SCE, are subject to a "cap" on their 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

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December 2024, 52% of retail sales by December 2027, and 60% of retail sales by December 2030. Approximately 38% of SCE's supply portfolio in 2019 came from renewable sources eligible under California's RPS. SCE estimates that approximately 35% of its 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. Separate from RPS targets, California also requires all retail electricity sales to be from carbon-free resources (such as hydroelectric energy) by 2045. In 2020 approximately 43% of SCE's customer deliveries came from carbon-free resources. California also supports climate action to meet the December 2015 Paris Agreement. SCE's climate change objectives align with California’s requirements, and SCE anticipates it will meet its own objectives, and therefore California’s requirements, through 2045.

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.

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 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

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. 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 "Management Overview—Wildfire Mitigation, Wildfire Insurance and Restoration Expenses" in the MD&A.

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.

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."

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LEGAL PROCEEDINGS

2017/2018 Wildfire/Mudslide Events

See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" for information regarding legal proceedings related to the 2017/2018 Wildfire/Mudslide Events.

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 $1,000,000.

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"). See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Environmental Remediation" for information regarding the Mission Canyon Incident.

MINE SAFETY DISCLOSURE

Not applicable.

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CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL

INFORMATION ABOUT OUR EXECUTIVE OFFICERS

Executive Officer

Age at February 18, 2021

Company Position

Pedro J. Pizarro

55

President and Chief Executive Officer

Maria Rigatti

57

Executive Vice President and Chief Financial Officer

Adam S. Umanoff

61

Executive Vice President and General Counsel

Caroline Choi

52

Senior Vice President, Corporate Affairs

J. Andrew Murphy

60

Senior Vice President, Strategy and Corporate Development

Jacqueline Trapp

53

Senior Vice President, Human Resources

Kevin M. Payne

60

President and Chief Executive Officer, SCE

Steven D. Powell

42

Executive Vice President, Operations, SCE

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, Edison International's 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, 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 President, Edison International President, SCE

October 2016 to present June 2016 to September 2016 October 2014 to June 2016

Maria Rigatti

Executive Vice President and Chief Financial Officer, Edison International Senior Vice President and Chief Financial Officer, SCE

September 2016 to present July 2014 to September 2016

Adam S. Umanoff

Executive Vice President and General Counsel, Edison International

January 2015 to present

Caroline Choi

Senior Vice President, Corporate Affairs, Edison International and SCE Senior Vice President, Regulatory Affairs, SCE Vice President Energy & Environmental Policy, SCE

February 2019 to present June 2016 to February 2019 January 2012 to June 2016

J. Andrew Murphy

Senior Vice President, Strategy and Corporate Development, Edison International

September 2015 to present

Jacqueline Trapp

Senior Vice President, Human Resources Edison International and SCE Vice President, Human Resources, SCE Director, Executive Talent and Rewards, Edison International

February 2018 to present June 2016 to February 2018 July 2012 to June 2016

Kevin M. Payne

President and Chief Executive Officer, SCE Chief Executive Officer, SCE Senior Vice President, Customer Service, SCE

June 2019 to present June 2016 to June 2019 March 2014 to June 2016

Steven D. Powell

Executive Vice President, Operations, SCE Senior Vice President, Strategy, Planning and Operational Performance, SCE Vice President, Strategy & Integrated Planning, SCE Director, Organizational Performance, SCE

September 2019 to present August 2018 to September 2019 February 2016 to August 2018 January 2015 to February 2016

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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 "Item 1: Election of Directors," and is incorporated herein by this reference.

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.

EXECUTIVE COMPENSATION

Information responding to this section will appear in the Edison International Proxy Statement under the headings "Compensation Discussion and Analysis," "Executive Compensation" and "Director Compensation" and is incorporated herein by this reference.

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 Transactions," and "Governance Structure and Processes—Director Independence," 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 headings "Stock Ownership" and "Item 4: Approval of the EIX Employee Stock Purchase Plan" 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 2020. 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, 2020 and December 31, 2019:

						SCE ($000)
Type of Fee						2020			2019
Audit Fees(1)						$	5,600		$	5,329
Audit-Related Fees(2)						255			785
Tax Fees(3)						260			366
All Other Fees(4)						1,359			238
Total						$	7,474		$	6,718

(1) These represent fees for professional services provided in connection with the audit of SCE’s annual financial statements and internal controls over financial reporting, and reviews of SCE's quarterly financial statements.

(2) These 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.

(3) These represent 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 cases.

(4) These represent fees for miscellaneous services including CSRP assessment and a CPUC required attestation report on wildfire memorandum accounts.

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 2020 services in the audit, audit-related, tax and other categories. The committee’s deliberations consider balancing the design of

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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, 2020, 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 on 1934.

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

Edison International

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 the MD&A under the heading "Liquidity and Capital Resources—SCE—SCE Dividends," and 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 27,353 on February 18, 2021. In addition, Edison International cannot pay dividends if it does not meet California law requirements on retained earnings and solvency.

Southern California Edison Company

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 the MD&A under the heading "Liquidity and Capital Resources—SCE—SCE Dividends," and in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."

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Comparison of Five-Year Cumulative Total Return

			At December 31,
						2015						2016						2017						2018						2019						2020
Edison International						$	100					$	125					$	113					$	106					$	145					$	127
S & P 500 Index						$	100					$	112					$	136					$	130					$	171					$	203
Philadelphia Utility Index						$	100					$	117					$	132					$	137					$	174					$	179

Note: Assumes $100 invested on December 31, 2015 in stock or index including reinvestment of dividends. Performance of the Philadelphia Utility 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.

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FORM 10-K SUMMARY

None.

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

Edison International

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
Schedule II – Valuation and Qualifying Accounts of Edison International

Schedules III through V, inclusive, for Edison International are omitted as not required or not applicable.

Southern California Edison Company

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
Schedule II – Valuation and Qualifying Accounts of SCE

Schedules I and III through V, inclusive, for SCE are omitted as not required or not applicable.

(a) (3) Exhibits

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Exhibit Index

Exhibit Number						Description
Edison International
3.1						Certificate of Restated Articles of Incorporation of Edison International, effective 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, 2006)*
3.2						Bylaws of Edison International, as amended effective October 25, 2018 (File No. 1-9936, filed as Exhibit No. 3.1 to Edison International's Form 10-Q for the quarter ended September 30, 2018)*
Southern California Edison Company
3.3						Restated Articles of Incorporation of Southern California Edison Company, effective March 2, 2006, together with all Certificates of Determination of Preference Stock issued since March 2, 2006 (File No. 1-2313 filed as Exhibit 3.1 to SCE's Form 10-Q for the quarter ended June 30, 2017)*
3.4						Bylaws of Southern California Edison Company, as amended effective October 25, 2018 (File No. 1-9936, filed as Exhibit No. 3.2 to SCE's Form 10-Q for the quarter ended September 30, 2018)*
Edison International
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)*
Southern California Edison Company
4.3						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)*
4.4						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)*
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, 2021 (File No. 1-9936, filed as Exhibit No. 10.3 for the quarter ended September 30, 2020)*
10.4**						Executive Grantor Trust Agreement, dated August 1995 (File No. 1-9936, filed as Exhibit 10.12 to Edison International's Form 10-K for the year ended December 31, 1995)*
10.4.1**						Executive Grantor Trust Agreement Amendment 2002-1, effective May 14, 2002 (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended June 30, 2002)*
10.4.2**						Executive and Director Grantor Trust Agreements Amendment 2008-1 (File No. 1-9936, filed as Exhibit No. 10.6.2 to Edison International's Form 10-K for the year ended December 31, 2008)*
10.5**						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)*
10.5.1**						Edison International 2008 Executive Retirement Plan, as amended and restated effective January 1, 2021 (File No. 1-9936, filed as Exhibit 10.4 to Edison International and SCE's Form 10-Q for the quarter ended September 30, 2020)*
10.6**						Edison International Executive Incentive Compensation Plan, as amended and restated effective February 27, 2019 (File No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the year ended March 31, 2019)*

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Exhibit Number						Description
10.7**						Edison International 2008 Executive Disability Plan, as amended and restated effective April 2, 2018 (File No. 1-9936, filed as Exhibit No. 10.4 to Edison International and SCE's Form 10-Q for the quarter ended March 31, 2018)*
10.8**						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)*
10.8.1**						Edison International 2010 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, 2010)*
10.8.2**						Edison International 2011 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, 2011)*
10.8.3**						Edison International 2012 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, 2012)*
10.8.4**						Edison International 2013 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, 2013)*
10.8.5**						Edison International 2014 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, 2014)*
10.8.6**						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)*
10.8.7**						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)*
10.8.8**						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)*
10.8.9**						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)*
10.8.10**						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)*
10.8.11**						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)*
10.9**						Edison International 2008 Executive Severance Plan, as amended and restated effective April 2, 2018 (File No. 1-9936, filed as Exhibit 10.5 to Edison International's Form 10-Q for the quarter ended March 31, 2018)*
10.10**						Edison International and Southern California Edison Company Director Compensation Schedule, as adopted August 27, 2020 (File No. 1-9936, filed as Exhibit 10.1 to Edison International and SCE's Form 10-Q for the quarter ended September 30, 2020)*
10.11**						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)*
10.12						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)*
10.13						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)*
10.13.1						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)*
10.13.2						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)*
10.13.3						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)*

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Exhibit Number						Description
10.14**						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)*
10.15						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)*
10.16						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 Southern California Edison Company's Form 8-K dated and filed May 18, 2018)*
10.17						364-Revolving Credit Agreement, dated as of March 11, 2020, among Southern California Edison, the several banks and other financial institutions from time to time parties thereto, and Royal Bank of Canada, as administrative agent for the lenders. (File No. 1-2313, filed as Exhibit 10.1 to Southern California Edison Company's Form 8-K dated and filed March 11, 2020)*
10.18						Term Loan Credit Agreement, dated as of March 11, 2020, among Southern California Edison Company, the several banks and other financial institutions from time to time parties thereto, and Royal Bank of Canada, as administrative agent for the lenders. (File No. 1-2313, filed as Exhibit 10.2 to Southern California Edison Company's Form 8-K dated and filed March 11, 2020)*
10.19						Term Loan Credit Agreement, dated as of March 20, 2020, among Edison International, the several banks and other financial institutions from time to time parties thereto, JPMorgan Chase Bank, N.A., as administrative agent for the lenders, and Citibank, N.A., as syndication agent. (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated March 20,2020 and filed March 24, 2020)*
10.20						364-Revolving Credit Agreement dated as of May 8, 2020, among Southern California Edison Company, the several banks and other financial institutions from time to time parties thereto, JPMorgan Chase Bank, N.A., as administrative agent, and Citibank, N.A., Mizuho Bank, Ltd., MUFG Bank, Ltd., Barclays Bank PLC, and Bank of America N.A. as co-syndication agents. (Filed No. 1-2313, filed as Exhibit 10.1 to Southern California Edison Company's Form 8-K dated and filed May 8, 2020)*
21						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
101.1						Financial statements from the annual report on Form 10-K of Edison International for the year ended December 31, 2020, filed on February 25, 2021, formatted in Inline XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; (v) Consolidated Statements of Changes in Equity and (vi) the Notes to Consolidated Financial Statements
101.2						Financial statements from the annual report on Form 10-K of Southern California Edison Company for the year ended December 31, 2020, filed on February 25, 2021, formatted in Inline XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; (v) Consolidated Statements of Changes in Equity and (vi) the Notes to Consolidated Financial Statements

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Exhibit Number						Description
104						The cover page of this report formatted in Inline XBRL (included as Exhibit 101)

________________________________________

*    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.

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Schedules Supplementing Financial Statements

EDISON INTERNATIONAL

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT

CONDENSED BALANCE SHEETS

			December 31,
(in millions)			2020						2019
Assets:
Cash and cash equivalents			$	3					$	15
Other current assets			43						260
Total current assets			46						275
Investments in subsidiaries			17,706						16,530
Deferred income taxes			675						608
Other long-term assets			71						76
Total assets			$	18,498					$	17,489
Liabilities and equity:
Short-term debt			$	129					$	—
Current portion of long-term debt			—						400
Other current liabilities			636						481
Total current liabilities			765						881
Long-term debt			3,133						2,733
Other long-term liabilities			552						572
Total equity			14,048						13,303
Total liabilities and equity			$	18,498					$	17,489

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EDISON INTERNATIONAL

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT

CONDENSED STATEMENTS OF INCOME

For the Years Ended December 31, 2020, 2019 and 2018

(in millions)			2020						2019						2018
Interest income from affiliates			$	1					$	5					$	—
Operating, interest and other expenses			189						150						98
Loss before equity in earnings (loss) of subsidiaries			(188)						(145)						(98)
Equity in earnings (loss) of subsidiaries			851						1,385						(376)
Income (loss) before income taxes			663						1,240						(474)
Income tax benefit			(76)						(44)						(17)
Income (loss) from continuing operations			739						1,284						(457)
Income from discontinued operations, net of tax			—						—						34
Net income (loss)			$	739					$	1,284					$	(423)

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

For the Years Ended December 31, 2020, 2019 and 2018

(in millions)			2020						2019						2018
Net income (loss)			$	739					$	1,284					$	(423)
Other comprehensive loss, net of tax			—						(9)						(7)
Comprehensive income (loss)			$	739					$	1,275					$	(430)

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EDISON INTERNATIONAL

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT

CONDENSED STATEMENTS OF CASH FLOWS

For the Years Ended December 31, 2020, 2019 and 2018

(in millions)			2020						2019						2018
Net cash provided by operating activities			$	1,171					$	181					$	785
Cash flows from financing activities:
Long-term debt issued			400						1,399						549
Long-term debt issuance costs			(3)						(9)						(4)
Long-term debt repaid			(400)						—						—
Short-term debt issued			800						1,000						—
Short-term debt repaid			(800)						(1,000)						—
Common stock issued			912						2,391						—
Payable due to affiliates			135						5						13
Commercial paper and other short-term borrowing (repayments), net			129						(1)						(1,141)
Payments for stock-based compensation			(3)						(27)						(24)
Receipts for stock-based compensation			21						39						14
Dividends paid			(928)						(810)						(788)
Net cash provided by (used in) financing activities			263						2,987						(1,381)
Capital contributions to affiliate			(1,446)						(3,258)						(10)
Dividends from affiliate			—						8						179
Net cash (used in) provided by investing activities:			(1,446)						(3,250)						169
Net decrease in cash and cash equivalents			(12)						(82)						(427)
Cash and cash equivalents, beginning of year			15						97						524
Cash and cash equivalents, end of year			$	3					$	15					$	97

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 $1.3 billion, $400 million and $788 million in 2020, 2019 and 2018, respectively.

Dividend Restrictions

CPUC holding company rules require that SCE's dividend policy be established by SCE's 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.

Effective January 1, 2020, the common equity component of SCE's CPUC authorized capital structure was increased from 48% to 52% on a weighted average basis over the January 1, 2020 to December 31, 2022 compliance period. Under AB 1054, the impact of SCE's contributions to the Wildfire Insurance Fund are excluded from the measurement of SCE's CPUC-jurisdictional authorized capital structure. For further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies."

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In May 2020, the CPUC issued a decision on SCE's application to the CPUC for 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 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. The temporary exclusion will lapse on May 7, 2022 or when a determination regarding cost recovery for the 2017/2018 Wildfire/Mudslide Events is made, whichever comes earlier. If the CPUC has not made a determination regarding cost recovery by May 7, 2022, SCE is permitted to file another application for a waiver of compliance with its equity ratio requirement. In the interim, 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. See "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."

Note 2. Debt and Equity Financing

Long-Term Debt

In April 2020, Edison International Parent issued $400 million of 4.95% senior notes due 2025. The proceeds were used to repay all $400 million of Edison International Parent's outstanding 2.125% Senior Notes due in 2020.

In addition, at December 31, 2020, Edison International Parent had $400 million of 2.40% senior notes due in 2022, $300 million of 3.125% senior notes due 2022, $400 million of 2.95% senior notes due in 2023, $500 million of 3.55% senior notes due 2024, $600 million of 5.75% senior notes due in 2027 and $550 million of 4.125% senior notes due in 2028. At December 31, 2019, Edison International Parent had $400 million of 2.125% senior notes due in 2020, $400 million of 2.40% senior notes due in 2022, $400 million of 2.95% senior notes due in 2023 and $550 million of 4.125% senior notes due in 2028.

Credit Agreements and Short-Term Debt

The following table summarizes the status of the credit facility at December 31, 2020:

(in millions)
Commitment			$	1,500
Outstanding borrowings 1			130
Amount available			$	1,370

1At December 31, 2020 Edison International Parent had $130 million outstanding commercial paper, net of discount, at a weighted-average interest rate of 0.42%. At December 31, 2019 Edison International Parent did not have any outstanding commercial paper.

In March 2020, Edison International Parent borrowed $800 million under a term loan agreement due in March 2021 with a variable interest rate based on LIBOR plus 1.125%. The proceeds were used for general corporate purposes. In May 2020, Edison International repaid the outstanding balance of the term loan using the proceeds from issuance of common stock in a registered direct offering.

The debt covenant in Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio of less than or equal to 0.70 to 1. At December 31, 2020, Edison International's consolidated debt to total capitalization ratio was 0.59 to 1.

Equity

In May 2020, Edison International issued 14,181,882 shares of common stock in a registered direct offering and received approximately $800 million in proceeds, before deducting fees and offering expenses of $14 million. The proceeds were used to pay off debt outstanding under a term loan agreement and for general corporate purposes. Refer to Note 2 for details of the term loan.

In May 2019, Edison International filed a prospectus supplement and executed several distribution agreements with certain sales agents to establish an "at-the-market" ("ATM") program under which it may sell shares of its common stock having an

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aggregate sales price of up to $1.5 billion. During the three months ended December 31, 2020, Edison International did not issue any shares through the ATM program. During the twelve months ended December 31, 2020, Edison International issued 391,501 shares through the ATM program and received proceeds of $27 million, net of fees and offering expenses of $0.3 million. During the three and twelve months ended December 31, 2019, Edison International issued 2,824,261 shares through the ATM program and received proceeds of $198 million, net of fees and offering expenses of $2 million. The proceeds from the sales were used for equity contributions to SCE and for general corporate and working capital purposes. As of December 31, 2020, shares of common stock having an aggregate offering price of $1.3 billion remained available to be sold under the ATM program. Edison International has no obligation to sell the remaining available shares.

Edison International continued to settle its ongoing common stock requirements of various internal programs through issuance of new common stock. During the twelve months ended December 31, 2020, 1,644,500 shares of common stock were purchased by employees through the 401(k) defined contribution savings plan for net cash receipts of $99 million, 387,425 shares of common stock were issued as stock compensation awards for net cash receipts of $16 million, 280,707 shares of new common stock were issued in lieu of distributing $17 million to shareholders opting to receive dividend payments in the form of additional common stock and 35,999 shares of common stock related to optional cash investments of $2 million.

During the twelve months ended December 31, 2019, 595,200 shares of common stock were purchased by employees through the 401(k) defined contribution savings plan for net cash receipts of $41 million, 423,569 shares of common stock were issued as stock compensation awards for net cash receipts of $22 million and 125,481 shares of new common stock were issued in lieu of distributing $8 million to shareholders opting to receive dividend payments in the form of additional common stock. Edison International did not have optional cash investment issuances in December 31, 2019.

Note 3. Related-Party Transactions

Edison International's Parent expense from services provided by SCE was $2 million in 2020, $2 million in 2019 and $2 million in 2018. Edison International's Parent interest expense from loans due to affiliates was $4 million in 2020 and $5 million in 2019 and 2018. Edison International Parent had current related-party receivables of $43 million and $272 million and current related-party payables of $323 million and $198 million at December 31, 2020 and 2019, respectively. Edison International Parent had long-term related-party receivables of $68 million and $73 million at December 31, 2020 and 2019, respectively, and long-term related-party payables of $219 million and $213 million at December 31, 2020 and 2019, respectively.

Edison Mission Energy ("EME"), a wholly-owned subsidiary of Edison International, emerged from bankruptcy in 2014 and retained a lease investment in a hydroelectric power plant in Vidalia, Louisiana. In November 2020, the lessee exercised an option in the lease agreement and purchased the asset upon expiration of the lease term. EME received net proceeds of $132 million from sale, which was transferred to Edison International Parent as a related-party note and included in current related-party payables.

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."

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EDISON INTERNATIONAL

SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS

									Additions
(in millions)			Balance at Beginning of Period						Charged to Costs and Expenses						Charged to Other Accounts						Deductions						Balance at End of Period
For the Year ended December 31, 2020
Allowance for uncollectible accounts
Customers			$	35.8					$	35.9					$	120.0		c			$	16.3					$	175.4
All others			13.9						9.4						—						10.8						12.5
Total allowance for uncollectible amounts			$	49.7					$	45.3					$	120.0					$	27.1		a			$	187.9
Tax valuation allowance			$	35.0					$	—					$	—					$	—					$	35.0
For the Year ended December 31, 2019
Allowance for uncollectible accounts
Customers			$	32.0					$	22.2					$	—					$	18.4					$	35.8
All others			19.5						10.0						—						15.6						13.9
Total allowance for uncollectible amounts			$	51.5					$	32.2					$	—					$	34.0		a			$	49.7
Tax valuation allowance			$	36.0					$	—					$	—					$	1.0					$	35.0
For the Year ended December 31, 2018
Allowance for uncollectible accounts
Customers			$	36.6					$	19.0					$	—					$	23.6					$	32.0
All others			17.3						16.2						—						14.0						19.5
Total allowance for uncollectible amounts			$	53.9					$	35.2					$	—					$	37.6		a			$	51.5
Tax valuation allowance			$	28.0					$	—					$	8.0		b			$	—					$	36.0

a    Accounts written off, net.

b    During 2018, Edison International recorded an additional valuation allowance of $4 million for non-California state net operating loss carryforwards and $4 million for California capital losses generated from the April 2018 sale of SoCore Energy, which are estimated to expire before being utilized.

c    Amounts are deferred to regulatory assets.

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SOUTHERN CALIFORNIA EDISON COMPANY

SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS

									Additions
(in millions)			Balance at Beginning of Period						Charged to Costs and Expenses						Charged to Other Accounts						Deductions						Balance at End of Period
For the Year ended December 31, 2020
Allowance for uncollectible accounts
Customers			$	35.5					$	35.6					$	120.0		b			$	15.9					$	175.2
All others			13.9						9.4						—						10.8						12.5
Total allowance for uncollectible accounts			$	49.4					$	45.0					$	120.0					$	26.7		a			$	187.7
For the Year ended December 31, 2019
Allowance for uncollectible accounts
Customers			$	31.6					$	22.0					$	—					$	18.1					$	35.5
All others			19.5						10.0						—						15.6						13.9
Total allowance for uncollectible accounts			$	51.1					$	32.0					$	—					$	33.7		a			$	49.4
For the Year ended December 31, 2018
Allowance for uncollectible accounts
Customers			$	36.0					$	18.9					$	—					$	23.3					$	31.6
All others			17.3						16.2						—						14.0						19.5
Total allowance for uncollectible accounts			$	53.3					$	35.1					$	—					$	37.3		a			$	51.1

a    Accounts written off, net.

b    Amounts are deferred to regulatory assets.

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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.

EDISON INTERNATIONAL

SOUTHERN CALIFORNIA EDISON COMPANY

By:

/s/ Aaron D. Moss

By:

/s/ Aaron D. Moss

Aaron D. Moss Vice President and Controller (Duly Authorized Officer and Principal Accounting Officer)

Aaron D. Moss Vice President and Controller (Duly Authorized Officer and Principal Accounting Officer)

Date:

February 25, 2021

Date:

February 25, 2021

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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)
Kevin Payne*						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)
William M. Petmecky III*						Senior Vice President and Chief Financial Officer (Southern California Edison Company)
C. Principal Accounting Officers
/s/ Aaron D. Moss						Vice President and Controller (Edison International)
Aaron D. Moss
/s/ Aaron D. Moss						Vice President and Controller (Southern California Edison Company)
Aaron D. Moss
D. Directors (Edison International and Southern California Edison Company, unless otherwise noted)
Jeanne Beliveau-Dunn*						Director
Michael C. Camuñez*						Director
Vanessa C.L. Chang*						Director
James T. Morris*						Director
Timothy T. O'Toole*						Director
Kevin Payne (SCE only)*						Director
Pedro J. Pizarro*						Director
Carey A. Smith*						Director
Linda G. Stuntz*						Director
William P. Sullivan*						Chair of the Edison International Board and Director
Peter J. Taylor*						Director
Keith Trent*						Director

*By:			/s/ Aaron D. Moss			*By:			/s/ Aaron D. Moss
			Aaron D. Moss Vice President and Controller (Attorney-in-fact for EIX Directors and Officers)						Aaron D. Moss Vice President and Controller (Attorney-in-fact for SCE Directors and Officers)
Date:			February 25, 2021			Date:			February 25, 2021

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