Resilience
Edison International and
Southern California Edison
2020 Annual Report
2020 FINANCIAL HIGHLIGHTS
Dollar amounts in millions, except per-share data
Years ended Dec. 31,
Operating revenue
Basic earnings (loss)(1)
Less: noncore items
2020
2019
2018
$13,578 $12,347 $12,657
$739
$1,284
$(423)
2017/2018 Wildfire/Mudslide Events claims
and expenses, net of recoveries
(899)
(157) (1,825)
Wildfire Insurance Fund expense
(242)
(109)
Sale of lease investment
Impairment and other
Remeasurement of tax assets and liabilities
Sale of SoCore Energy and other
Discontinued operations
96
83
15
–
–
–
(133)
88
–
–
–
–
9
54
(46)
34
Total noncore items (947)
(311)
(1,774)
Core earnings (1)
Basic earnings (loss) per share (1)
Core earnings per share (1)
Total assets at Dec. 31
Dividends paid per common share
Total shareholder return
Total employees
B U S I N E S S H I G H L I G H T S
Southern California Edison
Rate base (2)
Capital expenditures (3)
Peak demand (megawatts)
$1,686
$1,595
$1,351
$1.98 $3.78 $(1.30)
$4.52
$4.70
$4.15
$69,372 $64,382 $56,715
$2.55
$2.45
$2.42
(12.8)% 37.6% (6.7)%
13,351
12,937 12,574
$34,710
$32,592 $29,557
$5,536
$4,815 $4,363
23,133
22,009 23,766
Total system sales (kilowatt-hours, in millions)
85,399
84,654 87,143
(1) Edison International’s earnings are prepared in accordance with generally accepted accounting principles (GAAP) used in the
United States. Management uses core earnings and core earnings per share (EPS) internally for financial planning and for analysis
of performance. Core earnings and core EPS are also used when communicating with analysts and investors regarding our earnings
results to facilitate comparisons of the company’s performance from period to period. Core earnings and core EPS are non-GAAP
financial measures and may not be comparable to those of other companies. Core earnings and core EPS are defined as basic
earnings and basic EPS excluding income or loss from discontinued operations and income or loss from significant discrete items
that management does not consider representative of ongoing earnings. Basic earnings refer to net income attributable to Edison
International shareholders.
(2) Represents year-end rate base at Dec. 31, which includes capital expenditures related to certain FERC-approved projects during
the construction phase, and excludes rate base related to wildfire risk mitigation capital expenditures required by California Assembly
Bill 1054.
(3) Capital expenditures for each year include accruals.
EDISON INTERNATIONAL
Annual Meeting
Transfer Agent and Registrar
Inquiries may also
The Edison International annual
Equiniti Trust Company (EQ), which
be directed to:
meeting of shareholders will be held
maintains shareholder records,
EQ Shareowner Services
virtually on Thursday, April 22, 2021,
is the transfer agent and registrar
1110 Centre Point Curve, Suite 101
at 9 a.m., Pacific Time. The proxy
for Edison International’s common
Mendota Heights, MN 55120-4100
materials and information on how
stock and Southern California Edison
to attend the annual meeting are
Company’s preference stock. Share-
Fax:
available on our website at
holders may call EQ Shareowner
(651) 450-4033
www.edison.com/annualmeeting.
Services, (800) 347-8625, between
7 a.m. and 7 p.m. (Central Time),
EQ Shareowner Services
Corporate Governance
Monday through Friday, to speak
www.shareowneronline.com
Practices
with a representative (or to use
Information about Edison International’s
the interactive voice response unit
Investor Relations
corporate governance practices is
24 hours a day, seven days a
www.edisoninvestor.com
available on our website at
www.edison.com/corpgov.
week) regarding:
Email: invrel@edisonintl.com
Phone: (877) 379-9515
Online account information:
www.shareowneronline.com
Dividend Reinvestment and
Direct Stock Purchase Plan
A prospectus and enrollment forms
for Edison International’s common
stock Dividend Reinvestment and
Direct Stock Purchase Plan are
available from EQ Shareowner
Services upon request.
Edison International’s common stock is
payment addresses;
Stock Listing and
Trading Information
listed on the New York Stock Exchange
under the ticker symbol EIX; daily
newspapers list the stock as EdisonInt.
Shares of Southern California Edison
Company’s preference stock are not
listed on an exchange. SCE Trust II, SCE
Trust III, SCE Trust IV, SCE Trust V and
SCE Trust VI, subsidiaries of SCE, have
issued Trust Preference Securities,
which are listed on the New York
Stock Exchange.
n stock transfer and name-change
requirements;
n address changes, including dividend
n electronic deposit of dividends;
n taxpayer identification number
submissions or changes;
n duplicate 1099 and W-9 forms;
n notices of, and replacement of,
destroyed stock certificates and
dividend checks;
n Edison International’s Dividend
Reinvestment and Direct
Stock Purchase Plan, including
enrollments, purchases,
withdrawals, terminations,
transfers, sales, duplicate
statements and direct debit
of optional cash for dividend
reinvestment; and
n requests for access to online
account information.
2/26/21 12:34 AM
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
1-9936
Exact Name of Registrant
as specified in its charter
EDISON INTERNATIONAL
State or Other Jurisdiction of
Incorporation or Organization
California
1-2313
SOUTHERN CALIFORNIA EDISON COMPANY
California
IRS Employer
Identification Number
95-4137452
95-1240335
EDISON INTERNATIONAL
EDISON INTERNATIONAL
2244 Walnut Grove Avenue
(P.O. Box 976)
Rosemead, California 91770
(Address of principal executive offices)
(626) 302-2222
SOUTHERN CALIFORNIA EDISON COMPANY
2244 Walnut Grove Avenue
(P.O. Box 800)
Rosemead, California 91770
(Address of principal executive offices)
(626) 302-1212
(Registrant's telephone number, including area code)
(Registrant's telephone number, including area code)
Edison International:
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Common Stock, no par value
Trading Symbol(s)
EIX
Name of each exchange on which registered
NYSE LLC
Southern California Edison Company: 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 ☑
Securities registered pursuant to Section 12(g) of the Act: None
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
Smaller Reporting
Company
Emerging growth
company
Large Accelerated Filer Accelerated Filer
Non-accelerated Filer
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
Southern California Edison Company Wholly owned by Edison International
Approximately $20.5 billion
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)
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.
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.
DOCUMENTS INCORPORATED BY REFERENCE
OMISSION OF CERTAIN INFORMATION
(This page has been left blank intentionally.)
SEC Form 10-K
Reference Number
Part II, Item 7
TABLE OF CONTENTS
GLOSSARY..............................................................................................................................
vi
FORWARD-LOOKING STATEMENTS..............................................................................
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS......................................................................................
MANAGEMENT OVERVIEW.......................................................................................
Highlights of Operating Results.......................................................................................
Southern California Wildfires and Mudslides................................................................
COVID-19..........................................................................................................................
2021 General Rate Case....................................................................................................
Wildfire Mitigation, Wildfire Insurance and Restoration Expenses............................
Electricity Industry Trends..............................................................................................
Capital Program................................................................................................................
RESULTS OF OPERATIONS.........................................................................................
Southern California Edison Company............................................................................
Impact of 2018 GRC....................................................................................................
Years ended December 31, 2020, 2019 and 2018.......................................................
Earning Activities........................................................................................................
Cost-Recovery Activities..............................................................................................
Supplemental Operating Revenue Information.........................................................
Income Taxes...............................................................................................................
Edison International Parent and Other..........................................................................
Loss from Operations..................................................................................................
LIQUIDITY AND CAPITAL RESOURCES.................................................................
Southern California Edison Company............................................................................
Available Liquidity......................................................................................................
Regulatory Proceedings..............................................................................................
Capital Investment Plan..............................................................................................
Decommissioning of San Onofre................................................................................
i
1
3
3
3
5
9
9
10
11
11
13
13
13
14
15
16
16
16
17
17
17
17
19
19
22
24
SCE Dividends.............................................................................................................
Margin and Collateral Deposits..................................................................................
Regulatory Balancing and Memorandum Accounts..................................................
Edison International Parent and Other..........................................................................
Net Operating Loss and Tax Credit Carryforwards...................................................
Historical Cash Flows........................................................................................................
Southern California Edison Company.......................................................................
Edison International Parent and Other.....................................................................
Contractual Obligations and Contingencies...................................................................
Contractual Obligations..............................................................................................
Contingencies..............................................................................................................
Off-Balance Sheet Arrangements....................................................................................
Environmental Developments..........................................................................................
MARKET RISK EXPOSURES.......................................................................................
Interest Rate Risk..............................................................................................................
Commodity Price Risk......................................................................................................
Credit Risk.........................................................................................................................
CRITICAL ACCOUNTING ESTIMATES AND POLICIES......................................
Rate Regulated Enterprises..............................................................................................
Accounting for Contingencies..........................................................................................
Income Taxes.....................................................................................................................
Nuclear Decommissioning – Asset Retirement Obligation............................................
Pensions and Postretirement Benefits Other than Pensions..........................................
Contributions to the Wildfire Insurance Fund...............................................................
NEW ACCOUNTING GUIDANCE................................................................................
RISK FACTORS......................................................................................................................
RISKS RELATING TO EDISON INTERNATIONAL................................................
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY............
25
26
27
27
28
28
28
32
33
33
34
34
34
34
34
34
35
35
35
36
37
38
39
41
41
42
42
42
ii
Part I, Item 1A
Part II, Item 7A
Part II, Item 8
Regulatory and Legislative Risks.....................................................................................
Operating Risks.................................................................................................................
Financing Risks..................................................................................................................
Competitive and Market Risks.........................................................................................
Cybersecurity and Physical Security Risks.....................................................................
RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN
CALIFORNIA EDISON COMPANY.............................................................................
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK....
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA......................................
REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM..
CONSOLIDATED FINANCIAL STATEMENTS.........................................................
Consolidated Statements of Income for Edison International......................................
Consolidated Statements of Comprehensive Income for Edison International...........
Consolidated Balance Sheets for Edison International..................................................
Consolidated Statements of Cash Flows for Edison International...............................
Consolidated Statements of Changes in Equity for Edison International...................
Consolidated Statements of Income for Southern California Edison Company.........
Consolidated Statements of Comprehensive Income for Southern California
Edison Company................................................................................................................
Consolidated Balance Sheets for Southern California Edison Company....................
Consolidated Statements of Cash Flows for Southern California Edison Company..
Consolidated Statements of Changes in Equity for Southern California Edison
Company............................................................................................................................
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS...................................
Note 1. Summary of Significant Accounting Policies.....................................................
Note 2. Property, Plant and Equipment..........................................................................
Note 3. Variable Interest Entities.....................................................................................
Note 4. Fair Value Measurements....................................................................................
Note 5. Debt and Credit Agreements...............................................................................
Note 6. Derivative Instruments........................................................................................
Note 7. Revenue.................................................................................................................
iii
42
44
47
47
48
48
49
49
50
56
56
57
58
60
61
63
63
64
66
67
68
68
80
81
82
86
88
90
Note 8. Income Taxes........................................................................................................
Note 9. Compensation and Benefit Plans........................................................................
91
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
iv
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...............................................................................
Environmental Proceedings..............................................................................................
MINE SAFETY DISCLOSURES...........................................................................................
147
147
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............................
PRINCIPAL ACCOUNTANT FEES AND SERVICES.......................................................
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED
STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY
SECURITIES............................................................................................................................
Edison International..........................................................................................................
Part III, Item 12
Part III, Item 14
Part II, Item 5;
Part III, Item 12
149
149
150
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.
v
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
Edison International Proxy
Statement...........................
holding company for subsidiaries engaged in competitive businesses
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
vi
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
Montecito Mudslides.........
of Operations in this report
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...................................
RPS....................................
S&P.................................... Standard & Poor's Financial Services LLC
San Onofre......................... retired nuclear generating facility located in south San Clemente, California in which SCE
return on common equity
renewables portfolio standard
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
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.
Turnover Rate....................
US EPA.............................. U.S. Environmental Protection Agency
VCFD................................. Ventura County Fire Department
vii
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
the insurance fund established under AB 1054
Wildfire Insurance Fund....
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
viii
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;
1
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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.
2
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)
Net income (loss) attributable to Edison International
Continuing operations
SCE
Edison International Parent and Other
Discontinued operations
Edison International
Less: Non-core items
SCE
2017/2018 Wildfire/Mudslide Events claims and
expenses, net of recoveries
Wildfire Insurance Fund expense
Disallowed historical capital expenditures in SCE's
2018 GRC decision
Sale of San Onofre nuclear fuel
Re-measurement of tax assets and liabilities
Edison International Parent and Other
Sale of Vidalia lease
Goodwill impairment
Sale of SoCore Energy and other
Re-measurement of tax liabilities
Discontinued operations
Total non-core items
Core earnings (losses)
SCE
Edison International Parent and Other
Edison International
2020
2019
2020 vs 2019
Change
2018
$
810 $
1,409 $
(599) $
(71)
—
739
(899)
(242)
—
108
18
96
(25)
—
(3)
—
(125)
—
1,284
(157)
(109)
(123)
8
88
—
(18)
—
—
—
54
—
(545)
(742)
(133)
123
100
(70)
96
(7)
—
(3)
—
(310)
(147)
34
(423)
(1,825)
—
—
9
66
—
—
(46)
(12)
34
(947)
(311)
(636)
(1,774)
1,825
(139)
1,702
(107)
123
(32)
1,440
(89)
$
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.
4
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
6
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.
7
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."
8
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.
9
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
Regulatory deferral
Less: approved for recovery and transferred to BRRBA
Balance at December 31, 20201
1
Includes interest expense of $11 million.
$
$
868
1,225
(628)
1,465
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."
10
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
11
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)
Traditional capital expenditures
Distribution
Transmission
Generation
Subtotal
Wildfire mitigation-related capital expenditures
2020
2021
2022
2023
Total
2021 – 2023
$
3.8 $
0.7
0.2
4.7
0.8
3.4 $
0.7
0.2
4.3
1.2
3.3 $
0.7
0.2
4.2
1.1
3.3 $
0.6
0.2
4.1
1.3
10.0
2.0
0.6
12.6
3.6
16.2
14.7
Total capital expenditures
$
5.5 $
5.5 $
5.3 $
5.4 $
Total capital expenditures using range case discussed above
* $
5.4 $
4.6 $
4.7 $
* 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)
Rate base for expected capital expenditures
Rate base for expected capital expenditures (using range case described
above)
2020
2021
2022
2023
$
33.8 $ 36.3 $
38.4 $
41.1
* $ 36.2 $
37.6 $
39.5
* Not applicable
For additional information, see "Liquidity and Capital Resources—SCE—Capital Investment Plan."
12
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.
13
Years ended December 31, 2020, 2019 and 2018
The following table is a summary of SCE's results of operations for the periods indicated:
(in millions)
2020
Cost-
Recovery
Activities
Earning
Activities
Total
Consolidated
Earning
Activities
2019
Cost-
Recovery
Activities
Total
Consolidated
Earning
Activities
2018
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
Operation and maintenance
2,280
1,243
3,523
2,073
863
2,936
1,972
730
Wildfire-related claims, net of
insurance recoveries
Wildfire Insurance Fund expense
Depreciation and amortization
Property and other taxes
Impairment and other (income)
expense
Other operating income
1,328
336
1,965
435
(150)
(1)
—
—
—
—
—
—
1,328
336
255
152
1,965
1,727
435
396
(150)
159
(1)
(4)
—
—
1
—
—
—
255
2,669
152
—
1,728
1,867
396
392
—
—
—
—
159
(12)
—
(4)
(7)
5,406
2,702
2,669
—
1,867
392
(12)
(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)
Interest expense
Other income
Income (loss) before income taxes
Income tax benefit
Net income (loss)
Preferred and preference stock
dividend requirements
Net income (loss) available for
common stock
Net income (loss) available for
common stock
Less: Non-core expense
Core earnings1
1,273
(757)
149
665
(277)
942
(95)
(11)
106
—
—
—
1,178
1,920
(75)
1,845
(321)
(85)
(768)
(738)
255
119
665
1,301
(277)
(229)
942
1,530
(1)
76
—
—
—
(739)
(671)
195
107
1,301
(885)
(229)
(696)
1,530
(189)
(2)
87
—
—
—
(406)
(673)
194
(885)
(696)
(189)
132
—
132
121
—
121
121
—
121
$
810 $ — $
810 $ 1,409 $ — $
1,409 $
(310) $ — $
(310)
$
$
810
(1,015)
1,825
$
$
1,409
(293)
1,702
$
$
(310)
(1,750)
1,440
1 See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results."
14
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.
15
•
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.
16
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:
(in millions)
Edison Energy Group and subsidiaries
Corporate expenses and other subsidiaries
Total Edison International Parent and Other
Less: Non-core items
Core losses1
Years ended December 31,
2020
2019
2018
$
$
$
$
(35) $
(24) $
(36)
(71) $
68
$
(101)
(125) $
(18) $
(139) $
(107) $
(78)
(69)
(147)
(58)
(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
17
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:
Credit Rating
Outlook
Moody's
Baa2
Stable
Fitch
BBB-
Stable
S&P
BBB
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."
18
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
Finance a portion of the
AB 1054 Capital
Expenditures 1, 2
$
65
800 $
495 $
— $
305
May 2020
May 2021
150
June 2019
May 2024
108
Total SCE:
Undercollections
related to COVID-19
and general corporate
purposes
Support commercial
paper borrowings and
general corporate
purposes 3
1,500
—
—
1,500
3,000
725
$
5,300 $
1,220 $
159
159 $
2,116
3,921
1 This 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.
2
SCE 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.
3 The 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
20
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.
21
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
West of Devers
Mesa Substation
Riverside Transmission Reliability
Alberhill System2
Eldorado-Lugo-Mohave Upgrade
Project
Lifecycle Phase
Construction $
Construction
Licensing
Licensing
Construction
Direct
Expenditures (in
millions)1
Inception to
Date
(in millions)1
Scheduled In-
Service Date
740 $
641
584
486
247
662
510
19
44
124
2021
2022
2026
—2
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."
22
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
23
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
24
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
25
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
Incremental collateral requirements for purchased power and fuel contracts resulting from a
potential downgrade of SCE's credit rating to below investment grade2
Incremental collateral requirements for purchased power and fuel contracts resulting from
adverse market price movement3
Posted and potential collateral requirements
$
$
177
31
19
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.
26
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.
27
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:
Long-term Issuer Credit Rating
Outlook
Moody's
Baa3
Stable
Fitch
BBB-
Stable
S&P
BBB
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)
Net cash provided by (used in) operating activities
Net cash provided by financing activities
Net cash used in investing activities
Net increase (decrease) in cash, cash equivalents, and restricted cash
2020
2019
2018
$
$
1,427
3,699
(5,094)
$
(91)
$
4,771
(4,678)
32
$
2
$
3,191
616
(4,300)
(493)
28
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,
2019
2018
2020
Change in cash flows
2020/2019
2019/2018
(in millions)
Net income (loss)
Non-cash items1
Subtotal
Contributions to Wildfire Insurance Fund
$
942 $
1,840
2,782
1,530 $
1,782
3,312
(95)
(2,457)
Changes in cash flow resulting from working capital2
Regulatory assets and liabilities, net
Other noncurrent assets and liabilities, net3
Net cash provided by (used in) operating activities
$
(136)
(1,799)
675
1,427 $
298
(1,278)
34
(91) $
(189)
1,291
1,102
—
(313)
(92)
2,494
3,191
$
(530)
2,210
2,362
(2,457)
(434)
(521)
641
1,518 $
611
(1,186)
(2,460)
(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
29
$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.
30
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)
Issuances of first and refunding mortgage bonds, net of (discount)
premium and issuance costs
Long-term debt matured or repurchased
Short-term debt borrowed
Short-term debt repaid
Commercial paper and other short-term borrowing (repayment), net
Capital contributions from Edison International Parent
Redemptions of preference stock
Payments of common stock dividends to Edison International
Payments of preferred and preference stock dividends
Other
2020
2019
2018
$
2,676
$
2,306
$
(699)
2,194
(326)
175
1,432
(308)
(1,332)
(118)
5
(82)
750
(750)
(171)
3,250
—
(400)
(121)
(11)
2,692
(639)
—
—
(520)
—
—
(788)
(121)
(8)
616
Net cash provided by financing activities
$
3,699
$
4,771
$
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)
Net cash used in operating activities:
Net earnings from nuclear decommissioning trust investments
SCE's decommissioning costs
Net cash provided by investing activities:
Proceeds from sale of investments
Purchases of investments
Net cash impact
2020
2019
2018
$
25
$
67
$
(223)
(172)
5,927
(5,730)
4,389
(4,283)
$
(1)
$
1
$
41
(140)
4,340
(4,231)
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).
31
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)
Net cash used in operating activities
Net cash provided by (used in) financing activities
Net cash provided by investing activities
Net decrease in cash, cash equivalents and restricted cash
Net Cash Used in Operating Activities
2020
2019
2018
$
$
(164)
$
(216)
$
28
123
132
—
(13)
$
(84)
$
(14)
(534)
61
(487)
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)
$
Dividends received from SCE
Capital contribution to SCE
Issuance of common stock
Long-term debt issuance, net of discount and issuance costs
Long-term debt repayments
Commercial paper and other short-term borrowing (repayment), net
Other
Net cash provided by (used in) financing activities
$
Net Cash Provided by Investing Activities
1,332
(1,432)
912
397
(400)
129
18
28
400
(3,250)
2,391
1,390
—
(1)
12
(788)
788
—
—
545
(15)
(1,091)
27
$
132
$
(534)
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.
32
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)
SCE:
Long-term debt maturities and interest1
Power purchase agreements2
Other operating lease obligations3
Purchase obligations:4
Other contractual obligations
Total SCE5,6,7
Edison International Parent and Other:
Long-term debt maturities and interest1
Other operating lease obligations
Total Edison International Parent and Other5
Total Edison International6,7
Total
Less than
1 year
1 to 3 years
3 to 5 years
$
30,078
$
35,488
240
368
66,174
3,750
4
3,754
1,734
3,144
39
46
4,963
126
1
127
$
$
2,761
6,003
2,189
4,585
58
86
39
82
8,908
6,895
1,319
2
1,321
1,055
1
1,056
7,951
$
69,928
$
5,090
$
10,229
$
More than
5 years
$
23,394
21,756
104
154
45,408
1,250
—
1,250
$
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.
33
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)
Edison International:
December 31, 2020
December 31, 2019
SCE:
December 31, 2020
December 31, 2019
Commodity Price Risk
Carrying Value
Fair Value
10% Increase
10% Decrease
$
20,337
$
23,824
$
23,132
$
18,343
20,137
19,413
17,204
15,211
20,365
16,892
19,700
16,213
24,557
20,913
21,071
17,619
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
34
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:
(in millions)
Increase in electricity prices by 10%
Decrease in electricity prices by 10%
Increase in gas prices by 10%
Decrease in gas prices by 10%
Credit Risk
$
December 31,
2020
2019
18 $
(18)
9
(9)
25
(25)
12
(12)
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
35
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
36
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.
37
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.
38
• 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)
Uniform increase in escalation rate of 1 percentage point
Increase to ARO and
Regulatory Asset at
December 31, 2020
$
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.
39
Edison International and SCE used the following critical assumptions to determine expense for pension and other
postretirement benefit for 2020:
(in millions)
Discount rate1
Expected long-term return on plan assets2
Assumed health care cost trend rates3
* Not applicable to pension plans.
Pension
Plans
Postretirement
Benefits Other
than Pensions
3.11 %
6.00 %
*
3.32 %
4.90 %
6.50 %
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:
(in millions)
Edison International
SCE
Increase in
discount
rate by 1%
Decrease in
discount
rate by 1%
Increase in
discount
rate by 1%
Decrease in
discount
rate by 1%
Change to projected benefit obligation for pension
$
(447)
$
Change to accumulated benefit obligation for PBOP
(289)
548
346
$
(404)
$
(288)
496
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.
40
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,
45
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
47
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
48
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
49
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
50
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.
51
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.
52
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
53
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
54
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.
55
CONSOLIDATED FINANCIAL STATEMENTS
Consolidated Statements of Income
Edison International
(in millions, except per share amounts)
Total operating revenue
Purchased power and fuel
Operation and maintenance
Wildfire-related claims, net of insurance recoveries
Wildfire Insurance Fund expense
Depreciation and amortization
Property and other taxes
Impairment and other (income) expense
Gain on sale of lease interest and other operating income
Total operating expenses
Operating income (loss)
Interest expense
Other income
Income (loss) from continuing operations before income taxes
Income tax benefit
Income (loss) from continuing operations
Income from discontinued operations, net of tax
Net income (loss)
Preferred and preference stock dividend requirements of SCE
Other noncontrolling interests
Net income (loss) attributable to Edison International common shareholders $
Amounts attributable to Edison International common shareholders:
Income (loss) from continuing operations, net of tax
Income from discontinued operations, net of tax
$
Net income (loss) attributable to Edison International common shareholders $
Basic earnings (loss) per common share attributable to Edison International
common shareholders:
Weighted average shares of common stock outstanding
Continuing operations
Discontinued operations
Total
Diluted earnings (loss) per common share attributable to Edison
International common shareholders:
Weighted average shares of common stock outstanding, including effect of
dilutive securities
Continuing operations
Discontinued operations
Total
$
$
$
$
Years ended December 31,
2020
2019
2018
$ 13,578
$ 12,347
$ 12,657
5,406
2,797
2,669
—
1,871
395
78
(7)
13,209
(552)
(734)
197
(1,089)
(739)
(350)
34
(316)
121
(14)
4,932
3,609
1,328
336
1,967
438
(116)
(133)
4,839
3,018
255
152
1,730
399
184
(5)
12,361
1,217
10,572
1,775
(841)
193
1,127
(278)
1,405
—
1,405
121
—
(902)
251
566
(305)
871
—
871
132
—
739
739
—
739
$
1,284
$
(423)
$
1,284
$
(457)
—
34
$
1,284
$
(423)
373
1.98
—
$
340
3.78
—
326
$
(1.40)
0.10
1.98
$
3.78
$
(1.30)
374
1.98
—
$
341
3.77
—
326
$
(1.40)
0.10
1.98
$
3.77
$
(1.30)
The accompanying notes are an integral part of these consolidated financial statements.
56
Consolidated Statements of Comprehensive Income
Edison International
(in millions)
Net income (loss)
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
Other
Other comprehensive loss, net of tax
Comprehensive income (loss)
Less: Comprehensive income attributable to noncontrolling interests
Years ended December 31,
2020
2019
2018
$
871 $ 1,405
$
(316)
—
—
—
871
132
(9)
—
(9)
1,396
121
(3)
(4)
(7)
(323)
107
Comprehensive income (loss) attributable to Edison International
$
739 $ 1,275
$
(430)
The accompanying notes are an integral part of these consolidated financial statements.
57
Consolidated Balance Sheets
(in millions)
ASSETS
Cash and cash equivalents
Receivables, less allowances of $188 and $50 for uncollectible accounts at respective dates
1,130
Accrued unbilled revenue
Inventory
Insurance receivable
Income tax receivables
Prepaid expenses
Regulatory assets
Wildfire Insurance Fund contributions
Other current assets
Total current assets
Nuclear decommissioning trusts
Other investments
Total investments
Utility property, plant and equipment, less accumulated depreciation and amortization of
$10,681 and $9,958 at respective dates
Nonutility property, plant and equipment, less accumulated depreciation of $94 and $86 at
respective dates
Total property, plant and equipment
Regulatory assets
Wildfire Insurance Fund contributions
Operating lease right-of-use assets
Long-term insurance receivables
Other long-term assets
Total long-term assets
Edison International
December 31,
2020
2019
$
87
$
68
788
488
364
—
118
214
1,009
323
188
3,560
4,562
64
4,626
521
405
708
68
281
1,314
323
224
5,061
4,833
53
4,886
47,653
44,198
186
47,839
7,120
2,443
1,088
75
860
87
44,285
6,088
2,767
693
1,715
648
11,586
11,911
Total assets
$ 69,372
$ 64,382
The accompanying notes are an integral part of these consolidated financial statements.
58
Consolidated Balance Sheets
(in millions, except share amounts)
LIABILITIES AND EQUITY
Short-term debt
Current portion of long-term debt
Accounts payable
Customer deposits
Regulatory liabilities
Current portion of operating lease liabilities
Wildfire-related claims
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes and credits
Pensions and benefits
Asset retirement obligations
Regulatory liabilities
Operating lease liabilities
Wildfire-related claims
Other deferred credits and other long-term liabilities
Total deferred credits and other liabilities
Total liabilities
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)
Accumulated other comprehensive loss
Retained earnings
Total Edison International's common shareholders' equity
Noncontrolling interests – preferred and preference stock of SCE
Total equity
$
Edison International
December 31,
2020
2019
2,398
1,029
1,980
243
569
215
2,231
1,612
10,277
19,632
5,368
563
2,930
8,589
873
2,281
2,910
23,514
53,423
5,962
(69)
8,155
14,048
1,901
15,949
$
550
479
1,752
302
972
80
—
1,388
5,523
17,864
5,078
674
3,029
8,385
613
4,568
3,152
25,499
48,886
4,990
(69)
8,382
13,303
2,193
15,496
Total liabilities and equity
$ 69,372
$ 64,382
The accompanying notes are an integral part of these consolidated financial statements.
59
Consolidated Statements of Cash Flows
Edison International
(in millions)
Cash flows from operating activities:
Net income (loss)
Less: Income from discontinued operations
Income (loss) from continuing operations
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization
Allowance for equity during construction
Impairment and other (income) expense
Gain on sale of lease interest and other operating income
Deferred income taxes
Wildfire Insurance Fund amortization expense
Other
Nuclear decommissioning trusts
Contributions to Wildfire Insurance Fund
Changes in operating assets and liabilities:
Receivables
Inventory
Accounts payable
Tax receivables and payables
Other current assets and liabilities
Regulatory assets and liabilities, net
Wildfire-related insurance receivable
Wildfire-related claims
Other noncurrent assets and liabilities
Net cash provided by (used in) operating activities
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
Long-term debt repaid or repurchased
Short-term debt borrowed
Short-term debt repaid
Common stock issued
Preferred and preference stock redeemed
Commercial paper and other short-term borrowing (repayments), net
Dividends and distribution to noncontrolling interests
Dividends paid
Other
Net cash provided by financing activities
Cash flows from investing activities:
Capital expenditures
Proceeds from sale of nuclear decommissioning trust investments
Purchases of nuclear decommissioning trust investments
Proceeds from sale of San Onofre nuclear fuel
Proceeds from sale of lease investment
Other
Net cash used in investing activities
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash at beginning of year
Cash, cash equivalents and restricted cash at end of year
Years ended December 31,
2019
2018
2020
$
$
871
—
871
1,405
—
1,405
$
2,029
(121)
(116)
(133)
(296)
336
36
(197)
(95)
(283)
(43)
87
113
4
(1,799)
932
(56)
(6)
1,263
3,073
(1,099)
2,994
(1,126)
912
(308)
304
(118)
(928)
23
3,727
(5,484)
5,927
(5,730)
158
132
26
(4,971)
19
70
89
$
1,803
(101)
184
(5)
(284)
152
34
(106)
(2,457)
(76)
(83)
288
88
(13)
(1,278)
285
(101)
(42)
(307)
3,696
(82)
1,750
(1,750)
2,391
—
(172)
(121)
(810)
1
4,903
(4,877)
4,389
(4,283)
11
—
82
(4,678)
(82)
152
70
$
$
(316)
34
(350)
1,940
(104)
78
(7)
(527)
—
42
(109)
—
(39)
(49)
(31)
32
(79)
(92)
(2,000)
4,669
(197)
3,177
3,237
(654)
—
—
—
—
(1,611)
(121)
(788)
19
82
(4,509)
4,340
(4,231)
3
—
158
(4,239)
(980)
1,132
152
The accompanying notes are an integral part of these consolidated financial statements.
60
Consolidated Statements of Changes in Equity
Edison International
(in millions, except per share amounts)
Equity Attributable to Common Shareholders
Noncontrolling
Interests
Accumulated
Other
Comprehensive
Loss
Common
Stock
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)
Other comprehensive loss
Cumulative effect of accounting changes
Contribution from tax equity investor
Common stock dividends declared ($2.4275
per share)
Dividends to noncontrolling interests
($1.020 - $1.195 per share for preferred
stock; $62.500 - $143.750 per share for
preference stock)
Stock-based compensation
Noncash stock-based compensation
Deconsolidation of SoCore Energy
—
—
—
—
—
—
—
19
—
—
(2)
(5)
—
—
—
—
—
—
(423)
(423)
(11)
121
(313)
—
10
—
(2)
5
—
—
—
24
(791)
(791)
—
—
(20)
—
—
—
—
(20)
—
19
—
—
(15)
—
—
—
—
(121)
—
—
—
(2)
5
24
(791)
(121)
(20)
19
(15)
Balance at December 31, 2018
$ 2,545 $
(50) $
7,964 $ 10,459 $ — $
2,193 $ 12,652
Net income
Other comprehensive loss
Cumulative effect of accounting changes
—
—
—
Common stock issued, net of issuance cost
2,421
Common stock dividends declared ($2.4750
per share)
Dividends to noncontrolling interests
($1.020 - $1.195 per share for preferred
stock; $62.500 - $143.750 per share for
preference stock)
Stock-based compensation
Noncash stock-based compensation
—
—
—
24
—
(9)
(10)
—
—
—
—
—
1,284
1,284
—
—
10
(9)
—
—
—
—
2,421
—
(849)
(849)
—
121
—
—
—
—
1,405
(9)
—
2,421
(849)
—
(27)
—
—
—
(27)
—
24
—
(121)
(121)
—
—
(27)
24
Balance at December 31, 2019
$ 4,990 $
(69) $
8,382 $ 13,303 $ — $
2,193 $ 15,496
Net income
Common stock issued, net of issuance cost
(Note 14)
Common stock dividends declared ($2.5750
per share)
Dividends to noncontrolling interests
($0.757 - $0.886 per share for preferred
stock; $62.500 - $143.750 per share for
preference stock)
Noncash stock-based compensation and
other
Redemption of preferred and preference
stock
—
942
—
—
30
—
—
—
—
—
—
—
739
739
—
132
—
942
—
(965)
(965)
—
—
—
871
942
(965)
—
(1)
—
—
—
(117)
(117)
29
—
1
30
—
—
(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.
61
(This page has been left blank intentionally.)
62
Consolidated Statements of Income
(in millions)
Operating revenue
Purchased power and fuel
Operation and maintenance
Wildfire-related claims, net of insurance recoveries
Wildfire Insurance Fund expense
Depreciation and amortization
Property and other taxes
Impairment and other (income) expense
Other operating income
Total operating expenses
Operating income (loss)
Interest expense
Other income
Income (loss) before taxes
Income tax benefit
Net income (loss)
Southern California Edison Company
Years ended December 31,
2020
2019
2018
$ 13,546
$ 12,306
$ 12,611
4,932
3,523
1,328
336
1,965
435
(150)
(1)
12,368
1,178
(768)
255
665
(277)
942
132
810
4,839
2,936
255
152
1,728
396
159
(4)
10,461
1,845
(739)
195
1,301
(229)
1,530
121
5,406
2,702
2,669
—
1,867
392
(12)
(7)
13,017
(406)
(673)
194
(885)
(696)
(189)
121
$
1,409
$
(310)
Less: Preferred and preference stock dividend requirements
Net income (loss) available for common stock
$
Consolidated Statements of Comprehensive Income
(in millions)
Net income (loss)
$
2020
Years ended December 31,
2019
$ 1,530
942
$
2018
(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
Other
Other comprehensive loss, net of tax
Comprehensive income (loss)
(2)
—
(2)
(11)
—
(11)
1
(5)
(4)
$
940
$ 1,519
$
(193)
The accompanying notes are an integral part of these consolidated financial statements.
63
Consolidated Balance Sheets
Southern California Edison Company
(in millions)
ASSETS
Cash and cash equivalents
Receivables, less allowances of $188 and $49 for uncollectible accounts at respective dates
1,126
Accrued unbilled revenue
Inventory
Insurance receivable
Insurance receivable from affiliate
Income tax receivables
Prepaid expenses
Regulatory assets
Wildfire Insurance Fund contributions
Other current assets
Total current assets
Nuclear decommissioning trusts
Other investments
Total investments
Utility property, plant and equipment, less accumulated depreciation and amortization of
$10,681 and $9,958 at respective dates
Nonutility property, plant and equipment, less accumulated depreciation of $86 and $80 at
respective dates
Total property, plant and equipment
Regulatory assets
Wildfire Insurance Fund contributions
Operating lease right-of-use assets
Long-term insurance receivables
Long-term insurance receivables due from affiliate
Other long-term assets
Total long-term assets
December 31,
2020
2019
$
55
$
24
777
488
364
—
—
148
213
1,009
323
184
3,530
4,562
46
4,608
521
405
440
268
69
280
1,314
323
216
5,017
4,833
37
4,870
47,653
44,198
180
47,833
7,120
2,443
1,085
75
—
843
83
44,281
6,088
2,767
689
912
803
595
11,566
11,854
Total assets
$ 69,286
$ 64,273
The accompanying notes are an integral part of these consolidated financial statements.
64
Consolidated Balance Sheets
Southern California Edison Company
(in millions, except share amounts)
LIABILITIES AND EQUITY
Short-term debt
Current portion of long-term debt
Accounts payable
Customer deposits
Regulatory liabilities
Current portion of operating lease liabilities
Wildfire-related claims
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes and credits
Pensions and benefits
Asset retirement obligations
Regulatory liabilities
Operating lease liabilities
Wildfire-related claims
Other deferred credits and other long-term liabilities
Total deferred credits and other liabilities
Total liabilities
Commitments and contingencies (Note 12)
Preferred and preference stock
Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and
outstanding at respective dates)
Additional paid-in capital
Accumulated other comprehensive loss
Retained earnings
Total equity
$
December 31,
2020
2019
2,268
1,029
1,983
243
569
214
2,231
1,294
9,831
16,499
6,783
144
2,930
8,589
871
2,281
2,708
24,306
50,636
$
550
79
1,779
302
972
79
—
1,298
5,059
15,132
6,451
237
3,029
8,385
610
4,568
2,975
26,255
46,446
1,945
2,245
2,168
5,387
(41)
9,191
18,650
2,168
3,939
(39)
9,514
17,827
Total liabilities and equity
$ 69,286
$ 64,273
The accompanying notes are an integral part of these consolidated financial statements.
65
Consolidated Statements of Cash Flows
(in millions)
Cash flows from operating activities:
Net income (loss)
Adjustments to reconcile to net cash provided by operating activities:
Southern California Edison Company
Years ended December 31,
2019
2018
2020
$
942
$
1,530
$
(189)
Depreciation and amortization
Allowance for equity during construction
Impairment and other (income) expense
Deferred income taxes
Wildfire Insurance Fund amortization expense
Other
Nuclear decommissioning trusts
Contributions to Wildfire Insurance Fund
Changes in operating assets and liabilities:
Receivables
Inventory
Accounts payable
Tax receivables and payables
Other current assets and liabilities
Regulatory assets and liabilities, net
Wildfire-related insurance receivable
Wildfire-related claims
Other noncurrent assets and liabilities
Net cash provided by (used in) operating activities
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
Long-term debt repaid or repurchased
Short-term debt borrowed
Short-term debt repaid
Capital contributions from Edison International Parent
Preferred and preference stock redeemed
Commercial paper and other short-term borrowing (repayment), net
Dividends paid
Other
Net cash provided by financing activities
Cash flows from investing activities:
Capital expenditures
Proceeds from sale of nuclear decommissioning trust investments
Purchases of nuclear decommissioning trust investments
Proceeds from sale of San Onofre nuclear fuel
Other
Net cash used in investing activities
Net increase (decrease) in cash, cash equivalents and restricted cash
2,021
(121)
(150)
(263)
336
17
(197)
(95)
(290)
(43)
63
141
(7)
(1,799)
932
(56)
(4)
1,427
2,676
(699)
2,194
(326)
1,432
(308)
175
(1,450)
5
3,699
(5,480)
5,927
(5,730)
158
31
(5,094)
32
1,798
(101)
159
(243)
152
17
(106)
(2,457)
(89)
(83)
307
178
(15)
(1,278)
285
(101)
(44)
(91)
2,306
(82)
750
(750)
3,250
—
(171)
(521)
(11)
4,771
(4,876)
4,389
(4,283)
11
81
(4,678)
2
Cash, cash equivalents and restricted cash at beginning of year
Cash, cash equivalents and restricted cash at end of year
24
56
$
22
24
$
$
1,931
(104)
(12)
(552)
—
28
(109)
—
(45)
(50)
(43)
(84)
(91)
(92)
(2,000)
4,669
(66)
3,191
2,692
(639)
—
—
—
—
(520)
(909)
(8)
616
(4,491)
4,340
(4,231)
3
79
(4,300)
(493)
515
22
The accompanying notes are an integral part of these consolidated financial statements.
66
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
Other comprehensive income
Cumulative effect of accounting change
Dividends declared on common stock
($1.3245 per share)
Dividends declared on preferred stock
($1.020 - $1.195 per share) and preference
stock ($62.500 - $143.750 per share)
Stock-based compensation
Noncash stock-based compensation
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
9
—
1
(5)
—
—
—
—
(189)
(189)
—
5
1
—
(576)
(576)
(121)
(11)
—
(121)
(11)
9
Balance at December 31, 2018
$
2,245 $ 2,168 $
680 $
(23) $
8,715
$
13,785
Net income
Other comprehensive loss
Cumulative effect of accounting change
Capital contribution from Edison
International Parent
Dividends declared on common stock
($1.3797 per share)
Dividends declared on preferred stock
($1.020 - $1.195 per share) and preference
stock ($62.500 - $143.750 per share)
Stock-based compensation
Noncash stock-based compensation
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
3,250
—
—
(3)
12
—
(11)
(5)
—
—
—
—
—
1,530
—
5
—
(600)
(121)
(15)
—
1,530
(11)
—
3,250
(600)
(121)
(18)
12
Balance at December 31, 2019
$
2,245 $ 2,168 $
3,939 $
(39) $
9,514
$
17,827
Net income
Other comprehensive loss
Capital contribution from Edison
International Parent
Dividends declared on common stock
($2.6030 per share)
Dividends declared on preferred stock
($0.757 - $0.886 per share) and preference
stock ($62.500 - $143.750 per share)
Stock-based compensation
Noncash stock-based compensation and other
—
—
—
—
—
—
—
Redemption of preferred and preference
stock
(300)
—
—
—
—
—
—
—
—
—
—
1,432
—
—
(5)
14
7
—
(2)
—
—
—
—
—
—
942
—
—
942
(2)
1,432
(1,132)
(1,132)
(117)
—
(1)
(15)
(117)
(5)
13
(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.
67
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.
68
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:
(in millions)
Money market funds
Edison International
SCE
December 31,
2020
2019
2020
2019
$
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:
(in millions)
Book balances reclassified to accounts payable
2020
2019
2020
2019
$
69
$
75
$
69
$
74
The following table sets forth the cash, cash equivalents and restricted cash included in the consolidated statements of cash
flows:
Edison International
SCE
December 31,
(in millions)
Edison International:
Cash and cash equivalents
Short-term restricted cash1
Total cash, cash equivalents, and restricted cash
SCE:
Cash and cash equivalents
Short-term restricted cash1
Total cash, cash equivalents, and restricted cash
December 31,
2020
December 31,
2019
$
$
$
$
87 $
2
89 $
55 $
1
56 $
68
2
70
24
—
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:
(in millions)
Beginning balance
Plus: current period provision for uncollectible accounts
Included in operation and maintenance expenses
Deferred to regulatory assets
Less: write-offs, net of recoveries
Ending balance
69
Year ended December 31,
2020
Customers
All others
$
35 $
14
36
120
16
$
175 $
9
—
10
13
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:
Generation plant
Distribution plant
Transmission plant
General plant and other
Estimated Useful Lives
10 years to 55 years
20 years to 65 years
45 years to 65 years
5 years to 60 years
Weighted Average Useful
Lives
36 years
48 years
54 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.
70
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.
71
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:
(in millions)
Beginning balance
Accretion1
Revisions
Liabilities settled
Ending balance
December 31,
2020
2019
$
3,029
$
3,031
160
(36)
(223)
$
2,930
$
166
4
(172)
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)
72
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:
(in millions)
Amortization of deferred financing
costs charged to interest expense
Revenue Recognition
Edison International
2020
2019
2018
2020
Years ended December 31,
SCE
2019
2018
$
32
$
30
$
30
$
27
$
26
$
26
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.
73
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.
74
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.
75
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
76
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.
77
EPS attributable to Edison International common shareholders was computed as follows:
(in millions, except per share amounts)
Basic earnings (loss) per share – continuing operations:
Income (loss) from continuing operations attributable to common
shareholders
Participating securities dividends
Income (loss) from continuing operations available to common
shareholders
Weighted average common shares outstanding
Basic earnings (loss) per share – continuing operations
Diluted earnings (loss) per share – continuing operations:
Income (loss) from continuing operations attributable to common
shareholders
Participating securities dividends
Income (loss) from continuing operations available to common
shareholders
Income impact of assumed conversions
Income (loss) from continuing operations available to common
shareholders and assumed conversions
Weighted average common shares outstanding
Incremental shares from assumed conversions1
Adjusted weighted average shares – diluted
Years ended December 31,
2020
2019
2018
$
739
$
1,284
$
—
739
373
1.98
739
—
739
—
739
373
1
374
—
1,284
340
3.78
1,284
—
1,284
—
1,284
340
1
341
3.77
(457)
—
(457)
326
(1.40)
(457)
—
(457)
—
(457)
326
—
326
Diluted earnings (loss) per share – continuing operations
$
1.98
$
$
(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
78
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.
79
Note 2.
Property, Plant and Equipment
SCE's property, plant and equipment included in the consolidated balance sheets is composed of the following:
(in millions)
Distribution
Transmission
Generation
General plant and other
Accumulated depreciation
Construction work in progress
Nuclear fuel, at amortized cost
December 31,
2020
2019
$
28,663
$
15,669
3,709
5,129
(10,681)
42,489
5,033
131
26,929
14,720
3,664
4,583
(9,958)
39,938
4,131
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)
Transmission systems:
Eldorado
Pacific Intertie
Generating station:
Palo Verde (nuclear)
Total
Plant in
Service
Construction
Work in
Progress
Accumulated
Depreciation
Nuclear Fuel
(at amortized cost)
Net Book
Value
Ownership
Interest
$
$
324 $
346
74 $
—
39 $
74
— $
—
359
272
2,113
2,783 $
53
127 $
1,609
1,722 $
131
131 $
688
1,319
79 %
50 %
16 %
In addition, SCE has ownership interests in jointly owned power poles with other companies.
80
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
81
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:
(in millions)
2020
Dividend income
Dividend distributions
2019
Dividend income
Dividend distributions
2018
Dividend income
Dividend distributions
Note 4.
Fair Value Measurements
Recurring Fair Value Measurements
Years ended December 31,
Trust II
Trust III
Trust IV
Trust V
Trust VI
$
$
$
$
$
$
20
20
20
20
20
20
$
$
$
16
16
16
16
16
16
$
$
$
17
17
17
17
17
17
$
$
$
16
16
16
16
16
16
24
24
24
24
24
24
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
82
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:
(in millions)
Assets at fair value
Derivative contracts
Other
Nuclear decommissioning trusts:
Stocks2
Fixed Income3
Short-term investments, primarily cash
equivalents
Subtotal of nuclear decommissioning trusts4
Total assets
Liabilities at fair value
Derivative contracts
Total liabilities
Net assets
December 31, 2020
Level 1
Level 2
Level 3
Netting
and
Collateral1
Total
$
$
—
39
1,908
519
447
2,874
2,913
—
—
$
6
23
—
2,113
52
2,165
2,194
10
10
120
—
—
—
—
—
120
12
12
$
(18)
$
—
—
—
—
—
(18)
(22)
(22)
108
62
1,908
2,632
499
5,039
5,209
—
—
$
2,913
$
2,184
$
108
$
4
$
5,209
83
(in millions)
Assets at fair value
Derivative contracts
Other
Nuclear decommissioning trusts:
Stocks2
Fixed Income3
Short-term investments, primarily cash
equivalents
Subtotal of nuclear decommissioning trusts4
Total assets
Liabilities at fair value
Derivative contracts
Total liabilities
Net assets
December 31, 2019
Level 1
Level 2
Level 3
Netting
and
Collateral1
Total
$
$
—
4
1,765
738
98
2,601
2,605
—
—
$
19
14
—
2,024
48
2,072
2,105
11
11
83
—
—
—
—
—
83
5
5
$
(15)
$
—
—
—
—
—
(15)
(15)
(15)
87
18
1,765
2,762
146
4,673
4,778
1
1
$
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:
(in millions)
Fair value of net assets at beginning of period
Purchases
Sales
Settlements
Total realized/unrealized gains (losses) 1,2
Fair value of net assets at end of period
December 31,
2020
2019
$
$
78
8
(5)
(117)
144
108
$
$
141
6
(5)
(60)
(4)
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.
84
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
Assets
Liabilities
Valuation Technique
Unobservable Input
Range (per MWh)
Weighted
Average (per
MWh)
Congestion revenue rights
December 31, 2020
$
120 $
12
Auction prices
December 31, 2019
83
5
Auction prices
CAISO CRR auction
clearing prices
CAISO CRR auction
clearing prices
$(9.67) - $300.47
$2.75
(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:
(in millions)
Edison International
SCE
December 31, 2020
December 31, 2019
Carrying
Value1
Fair
Value2
Carrying
Value1
Fair
Value2
$
20,337
$
23,824
$
18,343
$
17,204
20,365
15,211
20,137
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.
85
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:
(in millions)
Edison International Parent and Other:
Debentures and notes:
2022 – 2028 (2.40% to 5.75%)
Current portion of long-term debt
Unamortized debt discount/premium and issuance costs, net
$
Total Edison International Parent and Other
SCE:
First and refunding mortgage bonds:
2022 – 2050 (1.20% to 6.05%)
Pollution-control bonds:
2023 (2.63%)
Debentures and notes:
2029 – 2053 (5.06% to 6.65%)
Other long-term debt 1:
Current portion of long-term debt
Unamortized debt discount/premium and issuance costs, net
Total SCE
Total Edison International
$
December 31,
2020
2019
$
3,150
—
(17)
3,133
3,150
(400)
(18)
2,732
16,843
14,272
135
752
306
324
(1,029)
(80)
16,499
19,632
$
306
—
(79)
(119)
15,132
17,864
1
Subsequent 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)
2021
2022
2023
2024
2025
Liens and Security Interests
Edison
International
SCE
$
$
1,029
1,064
1,435
500
1,300
1,029
364
1,035
—
900
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.
86
Credit Agreements and Short-Term Debt
The following table summarizes the status of the credit facilities at December 31, 2020:
Use of proceeds
Commitment
Outstanding
borrowings
Outstanding
letters of credit
Amount
available
(in millions, except for rates)
Execution
date
Termination
date
Edison International Parent
LIBOR
plus
(bps)
June 2019
May 2024
128
Total Edison International Parent:
SCE
Support commercial paper
borrowings and general
corporate purposes 1, 4
March 2020 March 2021
Finance a portion of the
AB 1054 Capital
Expenditures 2
65
May 2020
May 2021
150
June 2019
May 2024
108
Total SCE:
Total Edison International:
Undercollections related to
COVID-19 and general
corporate purposes
Support commercial paper
borrowings and general
corporate purposes 3, 4
$
$
$
$
$
1,500 $
1,500 $
130 $
130 $
— $
— $
1370
1,370
800 $
495 $
— $
305
1,500
—
—
1,500
3,000
5,300 $
6,800 $
725
1,220 $
1,350 $
159
159 $
159 $
2,116
3,921
5,291
1 At 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.
2 This 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.
3 At 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.
4 The 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
Term loan
Maturity
LIBOR plus
(bps)
Use of Proceeds
March 2020
March 2021
Floating rate first and refunding mortgage bonds
60 Fund a portion of the AB 1054 Excluded Capital Expenditures
Issuance
Amount
$
475
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.
87
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.
88
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
(in millions)
Short-Term1 Long-Term2
Subtotal
Short-Term3 Long-Term
Subtotal
Net Asset
Commodity derivative contracts
Gross amounts recognized
$
103 $
23 $
126 $
16 $
6 $
22 $
104
Gross amounts offset in the
consolidated balance sheets
Cash collateral posted4
Net amounts presented in the
consolidated balance sheets
(12)
—
(6)
—
(18)
—
(12)
(4)
(6)
—
(18)
(4)
—
4
$
91 $
17 $
108 $
— $
— $
— $
108
(in millions)
Short-Term1 Long-Term2
Subtotal
Short-Term3 Long-Term
Subtotal
Net Asset
December 31, 2019
Derivative Assets
Derivative Liabilities
Commodity derivative contracts
Gross amounts recognized
Gross amounts offset in the
consolidated balance
sheets
Cash collateral posted4
Net amounts presented in the
consolidated balance sheets
$
94 $
8 $
102 $
14 $
2 $
16 $
86
(13)
—
(2)
—
(15)
—
(13)
—
(2)
—
(15)
—
$
81 $
6 $
87 $
1 $
— $
1 $
—
—
86
1
2
3
4
Included in "Other current assets" on Edison International's and SCE's consolidated balance sheets.
Included in "Other long-term assets" on Edison International's and SCE's consolidated balance sheets.
Included in "Other current liabilities" on Edison International's and SCE's consolidated balance sheets.
At 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.
89
The following table summarizes the components of SCE's economic hedging activity:
(in millions)
Realized gains (losses)
Unrealized gains (losses)
Notional Volumes of Derivative Instruments
Years ended December 31,
2020
2019
2018
$
$
87
17
(7)
$
(74)
26
82
The following table summarizes the notional volumes of derivatives used for SCE economic hedging activities:
Commodity
Electricity options, swaps and forwards
Natural gas options, swaps and forwards
Congestion revenue rights
Note 7. Revenue
Unit of
Measure
GWh
Bcf
GWh
Economic Hedges
December 31,
2020
2019
1,581
34
41,151
3,155
43
48,170
• 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
Cost-
Recovery
Activities
Earning
Activities
Total
Consolidated
Earning
Activities
2019
Cost-
Recovery
Activities
Total
Consolidated
Earning
Activities
2018
Cost-
Recovery
Activities
Total
Consolidated
$ 6,920 $ 5,539 $
12,459 $ 6,512 $ 4,655 $
11,167 $ 6,519 $ 5,611 $
12,130
548
539
1,087
166
973
1,139
41
440
481
(in millions)
Revenues from contracts with
customers1,2
Alternative revenue programs
and other operating
revenue3
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.
90
Note 8.
Income Taxes
Current and Deferred Taxes
The components of income tax (benefit) expense by location of taxing jurisdiction are:
(in millions)
Current:
Federal
State
Deferred:
Federal
State
Total continuing operations
Discontinued operations1
Total
Edison International
2020
2019
2018
2020
Years ended December 31,
SCE
2019
2018
$
$
$
13
(22)
(9)
$
—
6
6
(230)
(66)
(296)
(305)
—
(305)
$
(243)
(41)
(284)
(278)
—
(278)
$
(57)
(155)
(212)
(386)
(141)
(527)
(739)
(34)
(773)
$
$
$
12
(26)
(14)
$
—
14
14
(207)
(56)
(263)
(277)
—
(277)
$
(206)
(37)
(243)
(229)
—
(229)
$
(51)
(93)
(144)
(354)
(198)
(552)
(696)
—
(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.
91
The components of net accumulated deferred income tax liability are:
(in millions)
Deferred tax assets:
$
Property
Wildfire-related1
Nuclear decommissioning trust assets in excess of
nuclear ARO liability
Loss and credit carryforwards2
Regulatory asset
Pension and postretirement benefits other than
pensions, net
Other
Sub-total
Less: valuation allowance3
Total
Deferred tax liabilities:
Property
Regulatory liability
Nuclear decommissioning trust assets
Other
Total
Accumulated deferred income tax liability, net4
$
Edison International
SCE
December 31,
2020
2019
2020
2019
590
1,134
515
1,991
841
163
513
5,747
35
5,712
8,879
1,111
515
514
11,019
5,307
$
$
478
847
$
540
1,134
449
1,515
739
170
408
4,606
35
4,571
8,244
570
449
320
9,583
5,012
$
515
683
841
35
527
4,275
—
4,275
8,871
1,111
515
499
10,996
6,721
$
$
435
847
449
253
739
40
416
3,179
—
3,179
8,234
570
449
310
9,563
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:
(in millions)
Expire in 2021
Expire between 2022 to 2025
Expire between 2029 to 2042
No expiration date1
Total
Edison International
SCE
December 31, 2020
Loss
Carryforwards
Credit
Carryforwards
Loss
Carryforwards
Credit
Carryforwards
$
$
4
31
1,192
509
1,736
$
$
—
—
515
10
525
$
$
4
26
380
413
823
$
$
—
—
50
—
50
1 Under 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
92
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:
(in millions)
Income (loss) from continuing
operations before income taxes
Provision for income tax at federal
statutory rate of 21%
Increase in income tax from:
Items presented with related state
income tax, net:
State tax, net of federal benefit
Property-related
Change related to uncertain tax
positions1
Deferred tax re-measurement2
2018 GRC Final Decision
Corporate-owned life insurance
cash surrender value
Other
Total income tax benefit from
continuing operations
Effective tax rate
Edison International
2020
2019
2018
2020
Years ended December 31,
SCE
2019
2018
$
566
$ 1,127
$ (1,089)
$
665
$ 1,301
$
(885)
119
237
(229)
140
273
(186)
(61)
(320)
(15)
—
—
(8)
(20)
(22)
(303)
—
(88)
(80)
(8)
(14)
(168)
(275)
(66)
—
—
(8)
7
(52)
(320)
(19)
—
—
(8)
(18)
(13)
(303)
—
(88)
(80)
(8)
(10)
(155)
(275)
(71)
—
—
(8)
(1)
$
(305)
(53.9) %
$
(278)
(24.7) %
$
(739)
(67.9) %
$
(277)
(41.7) %
$
(229)
(17.6) %
$
(696)
(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.
93
Unrecognized Tax Benefits
The following table provides a reconciliation of unrecognized tax benefits for continuing and discontinued operations:
(in millions)
2020
2019
2018
2020
2019
2018
Edison International
SCE
December 31,
Balance at January 1,
Tax positions taken during the current
year:
Increases
$
370
$
338
$
432
$
282
$
249
$
331
55
46
41
56
47
42
Tax positions taken during a prior year:
Increases1
Decreases2
Settlements with taxing authorities3
Balance at December 31,
$
274
(20)
—
679
$
6
(20)
—
370
$
—
(108)
(27)
338
$
4
(22)
—
320
6
(20)
—
—
(121)
(3)
$
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)
Accrued interest and penalties
2020
2019
2020
2019
$
52
$
56
$
23
$
29
The net after-tax interest and penalties recognized in income tax expense (benefit) for continuing and discontinued operations
are:
(in millions)
Net after-tax interest and penalties
tax expense (benefit)
Edison International
2020
2019
2018
2020
December 31,
SCE
2019
2018
$
4
$
4
$
(62)
$
6
$
3
$
(25)
94
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:
(in millions)
2020
2019
2018
Edison
International
SCE
Years ended December 31,
$
$
93
82
74
92
81
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.
95
Information on pension plan assets and benefit obligations for continuing and discontinued operations is shown below.
(in millions)
Change in projected benefit obligation
Projected benefit obligation at beginning of year
Service cost
Interest cost
Actuarial loss
Benefits paid
Projected benefit obligation at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Funded status at end of year
Amounts recognized in the consolidated balance sheets consist of 1:
Current liabilities
Long-term liabilities
Amounts recognized in accumulated other comprehensive loss
consist of:
Prior service cost
Net loss1
Amounts recognized as a regulatory asset
Total not yet recognized as expense
Accumulated benefit obligation at end of year
Pension plans with an accumulated benefit obligation in excess of
plan assets:
Projected benefit obligation
Accumulated benefit obligation
Fair value of plan assets
Edison International
SCE
Years ended December 31,
2020
2019
2020
2019
$ 4,139
121
124
323
(231)
$ 4,476
$ 3,755
584
62
(230)
4,171
(305)
$
$ 3,880
114
155
240
(250)
$ 4,139
$ 3,321
611
73
(250)
3,755
(384)
$
$ 3,662
117
110
292
(197)
$ 3,984
$ 3,541
551
45
(197)
3,940
(44)
$
$ 3,431
110
138
199
(216)
$ 3,662
$ 3,124
576
57
(216)
3,541
(121)
$
(24)
(281)
(19)
(365)
$
(305)
$
(384)
$
(2)
(42)
(44)
(2)
(119)
$
(121)
$
(1)
$
(1)
$ —
$ —
96
95
12
95
94
87
$
107
$ 4,238
$
181
$ 3,968
16
16
12
28
$
$ 3,776
17
17
87
$
104
$ 3,529
4,476
4,238
4,171
4,139
3,968
3,755
3,984
3,776
3,940
3,662
3,529
3,541
Weighted average assumptions used to determine obligations at end
of year:
Discount rate
Rate of compensation increase
2.38 %
4.00 %
3.11 %
4.10 %
2.38 %
4.00 %
3.11 %
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
96
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:
(in millions)
Service cost
Non-service cost
Interest cost
Expected return on plan assets
Amortization of prior service cost
Amortization of net loss
Regulatory adjustment (deferred)
Total non-service benefit
Edison International
SCE
Years ended December 31,
2020
2019
2018
2020
2019
2018
$
121
$
114
$
126
$
119
$
111
$
123
124
(215)
2
10
16
(63)
155
(205)
2
7
(3)
(44)
140
(228)
3
9
15
(61)
114
(203)
1
7
16
(65)
143
(194)
2
5
(3)
(47)
128
(214)
3
6
15
(62)
61
Total expense recognized
$
58
$
70
$
65
$
54
$
64
$
Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing
operations:
(in millions)
Net loss
Amortization of net loss
Total recognized in other
comprehensive loss
Total recognized in expense and
other comprehensive loss
Edison International
SCE
Years ended December 31,
2020
2019
2018
2020
2019
2018
$
11
$
(10)
1
$
19
(7)
12
$
5
(9)
(4)
$
9
(7)
2
$
21
(5)
16
5
(6)
(1)
$
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:
Discount rate
Rate of compensation increase
Years ended December 31,
2020
2019
2018
3.11 %
4.10 %
4.19 %
4.10 %
3.46 %
4.10 %
Expected long-term return on plan assets
Interest crediting rate for cash balance account
6.50 %
6.50 %
6.00 %
Starting rate
Ultimate rate
Year ultimate rate is reached
3.61 %
5.00 %
2025
4.46 %
5.75 %
2022
4.36 %
5.75 %
2022
97
The following benefit payments, which reflect expected future service, are expected to be paid:
(in millions)
2021
2022
2023
2024
2025
2026 – 2030
Edison
International
$
294
297
298
299
302
SCE
$
254
259
262
266
268
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.
98
Information on PBOP Plan assets and benefit obligations is shown below:
(in millions)
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Actuarial (gain) loss
Plan participants' contributions
Benefits paid
Benefit obligation at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return on assets
Employer contributions
Plan participants' contributions
Benefits paid
Fair value of plan assets at end of year
Funded status at end of year
Amounts recognized in the consolidated balance sheets consist of:
Long-term assets
Current liabilities
Long-term liabilities
Edison International
SCE
Years ended December 31,
2020
2019
2020
2019
$ 2,083
38
63
(46)
29
(94)
$ 2,073
$ 2,465
309
8
29
(94)
2,717
644
$
$ 1,986
30
77
70
29
(109)
$ 2,083
$ 2,133
401
11
29
(109)
2,465
382
$
$ 2,074
37
63
(45)
29
(94)
$ 2,064
$ 2,464
309
8
29
(93)
2,717
653
$
$ 1,977
30
77
70
29
(109)
$ 2,074
$ 2,133
401
10
29
(109)
2,464
390
$
$
663
$
393
$
663
$
402
(10)
(9)
(11)
—
(10)
—
(12)
—
$
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
Weighted average assumptions used to determine obligations at end
$
(670)
$
(414)
$
(671)
$
(416)
of year:
Discount rate
Assumed health care cost trend rates:
Rate assumed for following year
Ultimate rate
Year ultimate rate reached
2.67 %
3.32 %
2.67 %
3.32 %
6.50 %
5.00 %
2029
6.50 %
5.00 %
2029
6.50 %
5.00 %
2029
6.50 %
5.00 %
2029
99
Net periodic PBOP expense components for continuing operations are:
(in millions)
Service cost
Non-service cost
Interest cost
Expected return on plan assets
Amortization of prior service credit
Amortization of net gain
Regulatory adjustment
Total non-service benefit
Edison International
SCE
Years ended December 31,
2020
2019
2018
2020
2019
2018
$
38
$
30
$
37
$
37
$
30
$
37
63
(119)
(1)
(29)
49
(37)
77
(111)
(1)
(17)
29
(23)
80
(121)
(1)
—
24
(18)
63
(119)
(1)
(29)
49
(37)
77
(111)
(1)
(17)
29
(23)
80
(122)
(1)
—
24
(19)
18
Total expense
$
1
$
7
$
19
$
—
$
7
$
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:
Discount rate
Expected long-term return on plan assets
Assumed health care cost trend rates:
Current year
Ultimate rate
Year ultimate rate reached
Years ended December 31,
2020
2019
2018
3.32 %
4.90 %
6.50 %
5.00 %
2029
4.35 %
5.30 %
6.75 %
5.00 %
2029
3.70 %
5.30 %
6.75 %
5.00 %
2029
The following benefit payments (net of plan participants' contributions) are expected to be paid:
(in millions)
2021
2022
2023
2024
2025
2026 – 2030
Edison
International
$
83
84
86
89
90
475
SCE
$
82
84
86
88
90
472
100
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,
101
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)
U.S. government and agency securities2
Corporate stocks3
Corporate bonds4
Common/collective funds5
Partnerships/joint ventures6
Other investment entities7
Registered investment companies8
Interest-bearing cash
Other
Total
Receivables and payables, net
Combined net plan assets available for benefits
SCE's share of net plan assets
Level 1
Level 2
NAV1
Total
$
151
570
—
—
—
—
69
7
—
$
1,006
$
5
601
—
—
—
—
—
39
—
—
—
1,017
569
137
23
—
—
$
1,157
575
601
1,017
569
137
92
7
39
$
797
$
1,651
$
1,746
$
4,194
(23)
4,171
3,940
$
102
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)
U.S. government and agency securities2
Corporate stocks3
Corporate bonds4
Common/collective funds5
Partnerships/joint ventures6
Other investment entities7
Registered investment companies8
Interest-bearing cash
Other
Total
Receivables and payables, net
Combined net plan assets available for benefits
SCE's share of net plan assets
Level 1
Level 2
NAV1
Total
$
146
547
—
—
—
—
133
7
—
$
992
$
7
572
—
—
—
—
—
79
—
—
—
693
471
130
—
—
—
$
1,138
554
572
693
471
130
133
7
79
$
833
$
1,650
$
1,294
$
3,777
(22)
3,755
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.
103
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)
U.S. government and agency securities2
Corporate stocks3
Corporate notes and bonds4
Common/collective funds5
Partnerships6
Registered investment companies7
Interest bearing cash
Other8
Total
Receivables and payables, net
Combined net plan assets available for benefits
SCE's share of net plan assets
Level 1
Level 2
NAV1
Total
$
$
380
224
$
30
3
—
—
—
65
—
—
1,079
—
—
—
26
132
$
—
—
—
693
81
—
—
—
410
227
1,079
693
81
65
26
132
$
669
$
1,270
$
774
$
2,713
4
2,717
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)
U.S. government and agency securities2
Corporate stocks3
Corporate notes and bonds4
Common/collective funds5
Partnerships6
Registered investment companies7
Interest bearing cash
Other8
Total
Receivables and payables, net
Combined net plan assets available for benefits
SCE's share of net plan assets
Level 1
Level 2
NAV1
Total
$
$
386
242
—
—
—
66
—
2
$
63
2
885
—
—
—
17
101
$
—
—
—
652
68
—
—
—
449
244
885
652
68
66
17
103
$
696
$
1,068
$
720
$
2,484
(19)
2,465
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%
104
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:
(in millions)
Stock-based compensation expense1:
Stock options
Performance shares
Restricted stock units
Other
Total stock-based compensation
expense
Income tax benefits related to stock
Edison International
2020
2019
2018
2020
Years ended December 31,
$
15
$
13
$
11
$
5
8
1
29
8
6
2
29
1
7
2
21
7
2
4
—
13
2018
$
SCE
2019
$
7
4
3
—
14
compensation expense
$
4
$
10
$
6
$
3
$
6
$
1 Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income.
Stock Options
6
1
4
—
11
3
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.
105
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:
Expected terms (in years)
Risk-free interest rate
Expected dividend yield
Weighted average expected dividend yield
Expected volatility
Weighted average volatility
Years ended December 31,
2020
5.2
0.4% - 0.6%
4.2% - 5.0%
4.7%
2019
5.5
1.6% - 2.3%
3.3% - 4.0%
3.9%
2018
5.7
2.6% - 3.0%
3.6% - 4.3%
3.8%
24.9% - 26.9%
21.7% -24.1%
20.9% - 21.9%
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
Granted
Forfeited or expired
Exercised1
Outstanding at December 31, 2020
Vested and expected to vest at December 31, 2020
9,278,677
$
1,993,954
(203,340)
(359,908)
10,709,383
10,391,796
Exercisable at December 31, 2020
6,489,876
$
SCE:
Outstanding at December 31, 2019
Granted
Forfeited or expired
Exercised1
Affiliate transfers, net
Outstanding at December 31, 2020
Vested and expected to vest at December 31, 2020
4,934,702
$
1,053,923
(189,691)
(302,911)
(5,535)
5,490,488
5,325,052
Exercisable at December 31, 2020
3,361,238
$
62.27
68.60
65.75
48.59
63.85
63.60
62.08
61.01
68.27
65.75
49.49
63.36
62.85
62.50
60.41
6.03
6.17
4.83
$
$
5.86
5.98
4.56
$
$
30
27
20
19
1 Edison International and SCE recognized tax benefits of $2 million and $2 million, respectively, from stock options exercised in 2020.
106
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:
Unrecognized compensation cost, net of expected forfeitures (in millions)
Weighted average period (in years)
Supplemental Data on Stock Options
Edison
International
$
17
2.3
SCE
$
9
2.3
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
Fair value of options vested
Value of options exercised
Performance Shares
$
8.18
$
8.80
$
8.21
$
8.16
$
8.83
$
8.22
2
9
14
27
14
10
2
7
7
19
7
7
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.
107
The following is a summary of the status of Edison International's nonvested performance shares:
Edison International:
Nonvested at December 31, 2019
Granted
Forfeited
Vested1
Equity Awards
Liability Awards
Weighted
Average
Grant Date
Fair Value
Shares
Weighted
Average
Grant Date
Fair Value
Shares
119,843
$ 66.03
113,186
$ 67.30
120,938
(7,157)
67.55
66.76
—
(3,825)
—
—
(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
Forfeited
Vested1
Affiliate transfers, net
64,133
(6,408)
—
(253)
67.15
66.78
—
(3,409)
—
(54,578)
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:
Nonvested at December 31, 2019
Granted
Forfeited
Vested
Affiliate transfers, net
Nonvested at December 31, 2020
Edison International
SCE
Restricted
Stock Units
Weighted
Average
Grant Date
Fair Value
Restricted
Stock Units
Weighted
Average
Grant Date
Fair Value
311,682
$
119,038
(11,294)
(85,553)
—
66.11
68.58
63.90
78.94
—
159,985
$
63,042
(10,095)
(42,549)
(1,963)
333,873
$
63.78
168,420
$
66.16
68.24
63.93
79.11
68.16
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.
108
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):
(in millions)
Stocks
Municipal bonds
U.S. government and agency securities
Corporate bonds
Short-term investments and receivables/payables1
Total
Longest
Maturity Date
—
2057
2067
2070
One-year
Amortized Cost
Fair Value
December 31,
2020
2019
2020
2019
N/A
1,013
740
460
281
N/A $
1,908 $
1,765
822
996
597
32
1,218
864
550
293
970
1,115
679
33
$
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:
(in millions)
Gross realized gains
Gross realized losses
Net unrealized gains (losses) for equity securities
December 31,
2020
2019
2018
$
255 $
(6)
176
87 $
(2)
343
134
(27)
(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.
109
Regulatory Assets
SCE's regulatory assets included on the consolidated balance sheets are:
(in millions)
Current:
December 31,
2020
2019
Regulatory balancing and memorandum accounts
$
1,127
$
Power contracts
Other
Total current
Long-term:
Deferred income taxes, net of liabilities
Pension and other postretirement benefits
Power contracts
Unamortized investments, net of accumulated amortization1
Unamortized loss on reacquired debt
Regulatory balancing and memorandum accounts
Environmental remediation
Other
Total long-term
Total regulatory assets
165
22
1,314
798
189
22
1,009
4,475
4,026
12
239
114
133
1,794
247
106
7,120
8,434
$
87
434
119
142
981
237
62
6,088
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.
110
Regulatory Liabilities
SCE's regulatory liabilities included on the consolidated balance sheets are:
(in millions)
Current:
December 31,
2020
2019
Regulatory balancing and memorandum accounts
$
471
$
Energy derivatives
Other
Total current
Long-term:
Costs of removal
Re-measurement of deferred taxes
Recoveries in excess of ARO liabilities
Regulatory balancing and memorandum accounts
Other postretirement benefits
Other
Total long-term
Total regulatory liabilities
87
11
569
2,595
2,283
1,930
1,062
671
48
8,589
9,158
$
$
883
80
9
972
2,674
2,424
1,569
1,261
416
41
8,385
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.
111
The following table summarizes the significant components of regulatory balancing and memorandum accounts included in
the above tables of regulatory assets and liabilities:
(in millions)
Asset (liability)
Energy resource recovery account
Portfolio allocation balancing account
New system generation balancing account
December 31,
2020
2019
$
(89)
$
497
(10)
(23)
537
85
Public purpose programs and energy efficiency programs
(1,130)
(1,244)
Base revenue requirement balancing account
Greenhouse gas auction revenue and low carbon fuel standard revenue
FERC balancing accounts
Wildfire and drought restoration accounts1
Wildfire-related memorandum accounts2
COVID-19-related memorandum accounts3
Other
Asset (Liability)
622
(125)
12
361
1,104
176
(30)
(328)
(196)
(127)
120
748
—
63
$
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.
112
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)
2021
2022
2023
2024
2025
Thereafter
Total future commitments1
Total
$
3,144
3,066
2,937
2,349
2,236
21,756
$ 35,488
1 Certain 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.
113
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
114
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
115
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
Increase in accrued estimated losses to reflect best estimate
Amounts paid
Loss estimate balance at December 31, 20201
$
4,541
1,297
(1,455)
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:
(in millions)
Charge for wildfire-related claims
Expected revenue from FERC customers
Total pre-tax charge
Income tax benefit
Total after-tax charge
Year ended December 31,
2020
2019
$
1,297
$
(84)
1,213
(339)
$
874
$
232
(14)
218
(61)
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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
Insurance recoveries
Balance at December 31, 2020
$
$
1,710
(1,002)
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
123
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
124
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.
125
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)
2021
2022
2023
2024
2025
Thereafter
Total lease payments
Amount representing interest3
Lease liabilities
PPA Operating
Leases1
Other Operating
Leases2
PPA Finance
Leases1
$
$
204
208
159
47
47
443
1,108
203
$
905
$
39
32
26
21
18
104
240
60
180
$
$
1
1
1
—
—
5
8
4
4
1 Excludes 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.
2 Excludes 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.
3 Lease 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)
Operating leases:
Operating lease ROU assets1
Current portion of operating lease liabilities
Operating lease liabilities
Total operating lease liabilities1
Finance leases included in:
Utility property, plant and equipment, gross
Accumulated depreciation
Utility property, plant and equipment, net
Other current liabilities
Other long-term liabilities
Total finance lease liabilities
December 31, 2020
December 31, 2019
$
$
$
$
1,085
$
214
871
1,085
$
4
—
4
—
4
4
$
$
689
79
610
689
14
(5)
9
1
8
9
1 During 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)
PPA leases:
Operating lease cost
Finance lease cost
Variable lease cost1
Total PPA lease cost
Other operating leases cost
Total lease cost
Year ended
December 31, 2020
Year ended
December 31, 2019
$
$
111
1
1,917
2,029
47
$
2,076
$
118
1
2,087
2,206
46
2,252
1
Includes lease costs from renewable energy contracts where payments are based on contingent
external factors such as wind, hydro and solar power generation.
127
Other information related to leases was as follows:
(in millions, except lease term and discount rate)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases
Year ended
December 31, 2020
Year ended
December 31, 2019
PPA leases
Other leases
Financing cash flows from PPA finance leases
ROU assets obtained in exchange for lease obligations:
PPA operating leases
Other operating leases
Weighted average remaining lease term (in years):
$
$
Operating leases
PPA leases
Other leases
PPA Finance leases
Weighted average discount rate:
Operating leases
PPA leases
Other leases
PPA Finance leases
Leases as Lessor
$
111
44
1
463
58
9.75
12.13
16.67
3.12 %
3.63 %
11.29 %
118
44
1
—
34
16.05
12.73
11.51
4.46 %
3.88 %
8.76 %
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
2022
2023
2024
2025
Thereafter
Total
$
$
11
10
8
7
6
128
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.
128
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
$
April 29, 2020
May 26, 2020
June 30, 2020
August 31, 2020
December 18, 2020
Total
$
269
200
319
100
219
325
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
129
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:
(in millions, except shares and per share amounts)
Cumulative preferred stock
$25 par value:
4.08% Series
4.24% Series
4.32% Series
4.78% Series
Preference stock
No par value:
Shares
Outstanding
Redemption
Price
Dividends
Declared
per Share
December 31,
2020
2019
$
—
—
—
—
25.50
25.80
28.75
25.80
$
0.757
$
0.786
0.801
0.886
$
—
—
—
—
350
220
275
325
300
475
16
30
41
33
350
400
275
325
300
475
6.25% Series E (cumulative)
5.10% Series G (cumulative)
5.75% Series H (cumulative)
5.375% Series J (cumulative)
5.45% Series K (cumulative)
5.00% Series L (cumulative)
350,000
1,000.00
62.500
88,004
2,500.00
127.500
110,004
2,500.00
143.750
130,004
2,500.00
134.375
120,004
2,500.00
136.250
190,004
2,500.00
125.000
SCE's preferred and preference stock
Less issuance costs
Edison International's preferred and preference stock
of utility
1,945
(44)
2,245
(52)
$
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:
(in millions)
Beginning balance
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications
Reclassified from accumulated other comprehensive loss1
Other2
Change
Ending balance
Edison International
SCE
Years ended December 31,
2020
2019
2020
2019
$
(69) $
(50) $
(39) $
(23)
(8)
8
—
—
$
(69) $
(14)
5
(10)
(19)
(69) $
(7)
5
—
(2)
(41) $
(14)
3
(5)
(16)
(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:
(in millions)
SCE other income and (expenses):
Years ended December 31,
2019
2018
2020
Equity allowance for funds used during construction
Increase in cash surrender value of life insurance policies and life
$
121
$
101
$
104
insurance benefits
Interest income
Net periodic benefit income – non-service components
Civic, political and related activities and donations
Other
Total SCE other income
Other income of Edison International Parent and Other:
Net periodic benefit costs – non-service components
Other
66
20
102
(42)
(12)
255
(2)
(2)
39
37
70
(46)
(6)
195
(3)
1
36
24
81
(44)
(7)
194
(2)
5
Total Edison International other income
$
251
$
193
$
197
131
Note 17. Supplemental Cash Flows Information
Supplemental cash flows information is:
(in millions)
Cash payments (receipts):
Edison International
SCE
Years ended December 31,
2020
2019
2018
2020
2019
2018
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
Preferred and preference stock
251
11
231
12
200
12
—
11
200
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:
(in millions)
Current insurance receivable due from affiliate
Long-term insurance receivables due from affiliate
Prepaid insurance1
1 Reflected in "Prepaid expenses" on SCE's consolidated balance sheets.
December 31,
2020
2019
$
268
$
—
56
—
803
10
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.
132
Note 19. Quarterly Financial Data (Unaudited)
Edison International's quarterly financial data is as follows:
(in millions, except per share amounts)
Operating revenue
Operating income (loss)
Net income (loss)
Net income (loss) attributable to common shareholders
Basic earnings (loss) per share:
Diluted earnings (loss) per share:
Dividends declared per share
(in millions, except per share amounts)
Operating revenue
Operating income
Net income
Net income attributable to common shareholders
Basic earnings per share:
Diluted earnings per share:
Dividends declared per share
SCE's quarterly financial data is as follows:
(in millions)
Operating revenue
Operating income (loss)
Net income (loss)
Net income (loss) available for common stock
Common dividends declared
(in millions)
Operating revenue
Operating income
Net income
Net income available for common stock
Common dividends declared
2020
Fourth
Third
Second
First
$
3,157
$
4,644
$
2,987
$
2,790
$
$
$
$
$
$
794
552
526
1.39
1.39
(379)
(242)
(288)
$
$
(0.76) $
(0.76) $
500
348
318
0.85
0.85
$
$
302
213
183
0.50
0.50
0.6625
0.6375
0.6375
0.6375
2019
Fourth
Third
Second
2,970
287
173
143
0.40
0.40
0.6375
$
$
$
3,741
636
502
471
1.36
1.35
0.6125
$
$
$
2,812
500
422
392
1.20
1.20
0.6125
$
$
$
First
2,824
352
308
278
0.85
0.85
0.6125
2020
Fourth
Third
Second
First
3,151
678
500
474
325
$
$
4,635
(364)
(218)
(264)
269
2,980
548
411
381
269
$
2,780
316
249
219
269
2019
Fourth
Third
Second
First
$
2,958
$
3,732
$
2,800
$
2,816
325
224
194
200
649
534
503
200
513
449
419
—
358
323
293
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.
133
SELECTED FINANCIAL DATA
Selected Financial Data: 2016 – 2020
(in millions, except per share amounts)
2020
2019
2018
2017
2016
Edison International
Operating revenue1
Operating expenses2
Income (loss) from continuing operations
Income from discontinued operations, net of tax
Net income (loss)
Net income (loss) attributable to common
shareholders
Weighted average shares of common stock
outstanding
Basic earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Diluted earnings (loss) per share:
Continuing operations
Discontinued operations
Total
$ 13,578
$ 12,347
$ 12,657
$ 12,320
$ 11,869
12,361
871
—
871
739
373
1.98
—
1.98
1.98
—
1.98
$
$
$
$
10,572
1,405
—
1,405
13,209
(350)
34
(316)
1,284
(423)
340
326
$
$
$
$
3.78
$
(1.40)
—
0.10
3.78
$
(1.30)
3.77
$
(1.40)
—
0.10
3.77
$
(1.30)
$
$
$
$
10,864
668
—
668
565
326
1.73
—
1.73
1.72
—
1.72
9,807
1,413
12
1,425
1,311
326
3.99
0.03
4.02
3.94
0.03
3.97
$
$
$
$
Dividends declared per share
Total assets3, 4
Long-term debt excluding current portion
Preferred and preference stock of utility
Common shareholders' equity
Southern California Edison Company
Operating revenue1
Operating expenses2
Net income (loss)
Net income (loss) available for common stock
2.5750
2.4750
2.4275
2.2325
1.9825
$ 69,372
$ 64,382
$ 56,715
$ 52,580
$ 51,319
19,632
1,901
14,048
17,864
2,193
13,303
14,632
2,193
10,459
11,642
2,193
11,671
10,175
2,191
11,996
$ 13,546
$ 12,306
$ 12,611
$ 12,254
$ 11,830
12,368
942
810
10,461
1,530
1,409
13,017
(189)
(310)
10,707
1,136
1,012
9,648
1,499
1,376
Total assets
$ 69,286
$ 64,273
$ 56,574
$ 51,515
$ 50,891
Long-term debt excluding current portion
Preferred and preference stock
Common shareholder's equity
Capital structure4:
Common shareholder's equity
Preferred and preference stock
Long-term debt
16,499
1,945
16,705
47.5 %
5.5 %
46.9 %
15,132
2,245
15,582
47.3 %
6.8 %
45.9 %
12,892
2,245
11,540
43.3 %
8.4 %
48.3 %
10,428
2,245
12,427
49.5 %
9.0 %
41.5 %
9,754
2,245
12,238
50.5 %
9.3 %
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.
134
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.
135
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)
Residential
Commercial
Industrial
Public authorities
Agricultural and other
Total
2020
2019
2018
4,531
4,499
4,478
577
9
46
20
575
10
46
21
572
10
46
21
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.
136
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.
137
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
Employee EEI Serious Injuries
Employee EEI SIF Rate1
Employee DART Rate2
Safety Tier 1 Contractor work-related fatalities
Safety Tier 1 Contractor EEI Serious Injuries
Safety Tier 1 Contractor DART Rate2
0
17
0.12
0.89
3
18
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:
Females
Racially/ethnically diverse
Racially/ethnically or gender
diverse
Employees2
32 %
61 %
70 %
Leaders3
26 %
49 %
60 %
Executives4
37 %
34 %
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.
138
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
139
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
140
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
Pedro J. Pizarro
Maria Rigatti
Adam S. Umanoff
Caroline Choi
J. Andrew Murphy
Jacqueline Trapp
Kevin M. Payne
Steven D. Powell
Age at
February 18, 2021
55
57
61
52
60
53
60
42
Company Position
President and Chief Executive Officer
Executive Vice President and Chief Financial Officer
Executive Vice President and General Counsel
Senior Vice President, Corporate Affairs
Senior Vice President, Strategy and Corporate Development
Senior Vice President, Human Resources
President and Chief Executive Officer, SCE
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
Pedro J. Pizarro
Company Position
President and Chief Executive Officer, Edison International
President, Edison International
President, SCE
Effective Dates
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
148
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:
Type of Fee
Audit Fees(1)
Audit-Related Fees(2)
Tax Fees(3)
All Other Fees(4)
Total
SCE ($000)
2020
2019
$
$
5,600 $
255
260
1,359
7,474 $
5,329
785
366
238
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
149
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."
150
Comparison of Five-Year Cumulative Total Return
Edison International
S & P 500 Index
Philadelphia Utility Index
At December 31,
2015
2016
2017
2018
2019
2020
$ 100 $ 125 $ 113 $ 106 $ 145 $ 127
$ 100 $ 112 $ 136 $ 130 $ 171 $ 203
$ 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.
151
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
152
Exhibit Index
Exhibit
Number
Description
Edison International
3.1
3.2
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)*
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
3.4
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)*
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
4.2
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)*
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
4.4
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)*
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**
10.2**
10.3**
10.4**
10.4.1**
10.4.2**
10.5**
10.5.1**
10.6**
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
153
Exhibit
Number
10.7**
10.8**
10.8.1**
10.8.2**
10.8.3**
10.8.4**
10.8.5**
10.8.6**
10.8.7**
10.8.8**
10.8.9**
Description
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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**
10.10**
10.11**
10.12
10.13
10.13.1
10.13.2
10.13.3
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)*
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)*
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)*
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)*
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)*
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)*
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)*
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)*
154
Exhibit
Number
10.14**
10.15
10.16
10.17
10.18
10.19
10.20
21
23.1
23.2
24.1
24.2
31.1
31.2
32.1
32.2
101.1
101.2
Description
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)*
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)*
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)*
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)*
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)*
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)*
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)*
Subsidiaries of the Registrants
Consent of Independent Registered Public Accounting Firm (Edison International)
Consent of Independent Registered Public Accounting Firm (Southern California Edison Company)
Powers of Attorney of Edison International and Southern California Edison Company
Certified copies of Resolutions of Boards of Edison International and Southern California Edison Company
Directors Authorizing Execution of SEC Reports
Certifications of the Chief Executive Officer and Chief Financial Officer of Edison International pursuant to
Section 302 of the Sarbanes-Oxley Act
Certifications of the Chief Executive Officer and Chief Financial Officer of Southern California Edison Company
pursuant to Section 302 of the Sarbanes-Oxley Act
Certifications of the Chief Executive Officer and the Chief Financial Officer of Edison International required by
Section 906 of the Sarbanes-Oxley Act
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
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
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
155
Exhibit
Number
104
Description
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.
156
Schedules Supplementing Financial Statements
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED BALANCE SHEETS
(in millions)
Assets:
Cash and cash equivalents
Other current assets
Total current assets
Investments in subsidiaries
Deferred income taxes
Other long-term assets
Total assets
Liabilities and equity:
Short-term debt
Current portion of long-term debt
Other current liabilities
Total current liabilities
Long-term debt
Other long-term liabilities
Total equity
Total liabilities and equity
December 31,
2020
2019
$
$
3
43
46
15
260
275
17,706
16,530
675
71
608
76
$ 18,498
$ 17,489
$
129
—
636
765
3,133
552
14,048
$
—
400
481
881
2,733
572
13,303
$ 18,498
$ 17,489
157
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)
Interest income from affiliates
Operating, interest and other expenses
Loss before equity in earnings (loss) of subsidiaries
Equity in earnings (loss) of subsidiaries
Income (loss) before income taxes
Income tax benefit
2020
2019
2018
$
1
$
5
$
189
(188)
851
663
(76)
739
—
739
150
(145)
1,385
1,240
(44)
1,284
—
—
98
(98)
(376)
(474)
(17)
(457)
34
Income (loss) from continuing operations
Income from discontinued operations, net of tax
Net income (loss)
$
$
1,284
$
(423)
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
For the Years Ended December 31, 2020, 2019 and 2018
(in millions)
Net income (loss)
Other comprehensive loss, net of tax
Comprehensive income (loss)
2020
2019
2018
$
$
739
—
739
$
1,284
$
(423)
(9)
(7)
$
1,275
$
(430)
158
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)
Net cash provided by operating activities
Cash flows from financing activities:
Long-term debt issued
Long-term debt issuance costs
Long-term debt repaid
Short-term debt issued
Short-term debt repaid
Common stock issued
Payable due to affiliates
Commercial paper and other short-term borrowing (repayments), net
Payments for stock-based compensation
Receipts for stock-based compensation
Dividends paid
Net cash provided by (used in) financing activities
Capital contributions to affiliate
Dividends from affiliate
Net cash (used in) provided by investing activities:
Net decrease in cash and cash equivalents
Cash and cash equivalents, beginning of year
Cash and cash equivalents, end of year
Note 1. Basis of Presentation
2020
2019
2018
$
1,171
$
181
$
785
400
(3)
(400)
800
(800)
912
135
129
(3)
21
(928)
263
(1,446)
—
1,399
(9)
—
1,000
(1,000)
2,391
5
(1)
(27)
39
(810)
2,987
(3,258)
8
(1,446)
(3,250)
(12)
15
3
$
(82)
97
15
$
$
549
(4)
—
—
—
—
13
(1,141)
(24)
14
(788)
(1,381)
(10)
179
169
(427)
524
97
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."
159
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
Outstanding borrowings 1
Amount available
$
$
1,500
130
1,370
1 At 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
160
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."
161
EDISON INTERNATIONAL
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
Additions
Balance at
Beginning
of
Period
Charged to
Costs and
Expenses
Charged to
Other
Accounts
Deductions
Balance at
End of
Period
35.9
$
120.0 c $
—
$
$
120.0
—
$
$
16.3
$
175.4
10.8
27.1 a $
$
—
12.5
187.9
35.0
(in millions)
For the Year ended December 31, 2020
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible amounts
Tax valuation allowance
For the Year ended December 31, 2019
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible amounts
Tax valuation allowance
For the Year ended December 31, 2018
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible amounts
Tax valuation allowance
a Accounts written off, net.
$
$
$
$
$
$
$
$
$
35.8
13.9
49.7
35.0
32.0
19.5
51.5
36.0
36.6
17.3
53.9
28.0
$
$
$
$
$
$
$
$
$
9.4
45.3
—
22.2
10.0
32.2
—
19.0
16.2
35.2
—
$
$
$
$
$
$
$
$
$
18.4
$
15.6
34.0 a $
$
1.0
$
23.6
$
—
—
—
—
—
—
$
—
8.0 b $
14.0
37.6 a $
$
—
35.8
13.9
49.7
35.0
32.0
19.5
51.5
36.0
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.
162
SOUTHERN CALIFORNIA EDISON COMPANY
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
Additions
Balance at
Beginning
of
Period
Charged to
Costs and
Expenses
Charged to
Other
Accounts
Deductions
Balance at
End of
Period
$
$
$
$
$
$
35.5
13.9
49.4
31.6
19.5
51.1
36.0
17.3
53.3
$
$
$
$
$
$
35.6
$
9.4
120.0 b $
—
45.0
$
120.0
$
15.9
$
175.2
10.8
26.7 a $
12.5
187.7
22.0
10.0
32.0
18.9
16.2
35.1
$
$
$
$
—
—
—
—
—
—
$
$
$
$
18.1
$
15.6
33.7 a $
35.5
13.9
49.4
23.3
$
14.0
37.3 a $
31.6
19.5
51.1
(in millions)
For the Year ended December 31, 2020
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible accounts
For the Year ended December 31, 2019
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible accounts
For the Year ended December 31, 2018
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible accounts
a Accounts written off, net.
b Amounts are deferred to regulatory assets.
163
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
164
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
A. Principal Executive Officers
Pedro J. Pizarro*
Title
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*
William M. Petmecky III*
C. Principal Accounting Officers
/s/ Aaron D. Moss
Aaron D. Moss
/s/ Aaron D. Moss
Aaron D. Moss
D. Directors (Edison International and
Southern California Edison Company,
unless otherwise noted)
Jeanne Beliveau-Dunn*
Michael C. Camuñez*
Vanessa C.L. Chang*
James T. Morris*
Timothy T. O'Toole*
Kevin Payne (SCE only)*
Pedro J. Pizarro*
Carey A. Smith*
Linda G. Stuntz*
Executive Vice President and Chief Financial Officer
(Edison International)
Senior Vice President and Chief Financial Officer
(Southern California Edison Company)
Vice President and Controller
(Edison International)
Vice President and Controller
(Southern California Edison Company)
Director
Director
Director
Director
Director
Director
Director
Director
Director
William P. Sullivan*
Chair of the Edison International Board and Director
Peter J. Taylor*
Keith Trent*
Director
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
165
(This page has been left blank intentionally.)
2017/2018 Wildfire/Mudslide Events claims
(899)
(157) (1,825)
2020 FINANCIAL HIGHLIGHTS
Dollar amounts in millions, except per-share data
Years ended Dec. 31,
Operating revenue
Basic earnings (loss)(1)
Less: noncore items
and expenses, net of recoveries
Wildfire Insurance Fund expense
Sale of lease investment
Impairment and other
Remeasurement of tax assets and liabilities
Sale of SoCore Energy and other
Discontinued operations
Core earnings (1)
Basic earnings (loss) per share (1)
Core earnings per share (1)
Total assets at Dec. 31
Dividends paid per common share
Total shareholder return
Total employees
B U S I N E S S H I G H L I G H T S
Southern California Edison
Rate base (2)
Capital expenditures (3)
Peak demand (megawatts)
2020
2019
2018
$13,578 $12,347 $12,657
$739
$1,284
$(423)
(242)
(109)
96
83
15
–
–
–
(133)
88
–
–
–
–
9
54
(46)
34
$1,686
$1,595
$1,351
$1.98 $3.78 $(1.30)
$4.52
$4.70
$4.15
$69,372 $64,382 $56,715
$2.55
$2.45
$2.42
(12.8)% 37.6% (6.7)%
13,351
12,937 12,574
$34,710
$32,592 $29,557
$5,536
$4,815 $4,363
23,133
22,009 23,766
Total noncore items (947)
(311)
(1,774)
Total system sales (kilowatt-hours, in millions)
85,399
84,654 87,143
(1) Edison International’s earnings are prepared in accordance with generally accepted accounting principles (GAAP) used in the
United States. Management uses core earnings and core earnings per share (EPS) internally for financial planning and for analysis
of performance. Core earnings and core EPS are also used when communicating with analysts and investors regarding our earnings
results to facilitate comparisons of the company’s performance from period to period. Core earnings and core EPS are non-GAAP
financial measures and may not be comparable to those of other companies. Core earnings and core EPS are defined as basic
earnings and basic EPS excluding income or loss from discontinued operations and income or loss from significant discrete items
that management does not consider representative of ongoing earnings. Basic earnings refer to net income attributable to Edison
International shareholders.
(2) Represents year-end rate base at Dec. 31, which includes capital expenditures related to certain FERC-approved projects during
the construction phase, and excludes rate base related to wildfire risk mitigation capital expenditures required by California Assembly
Bill 1054.
(3) Capital expenditures for each year include accruals.
385196_18196.20_EIX_AR_3 color_10K wrap_FINAL_CVR.indd 6-8
EDISON INTERNATIONAL
Annual Meeting
The Edison International annual
meeting of shareholders will be held
virtually on Thursday, April 22, 2021,
at 9 a.m., Pacific Time. The proxy
materials and information on how
to attend the annual meeting are
available on our website at
www.edison.com/annualmeeting.
Corporate Governance
Practices
Information about Edison International’s
corporate governance practices is
available on our website at
www.edison.com/corpgov.
Stock Listing and
Trading Information
Edison International’s common stock is
listed on the New York Stock Exchange
under the ticker symbol EIX; daily
newspapers list the stock as EdisonInt.
Shares of Southern California Edison
Company’s preference stock are not
listed on an exchange. SCE Trust II, SCE
Trust III, SCE Trust IV, SCE Trust V and
SCE Trust VI, subsidiaries of SCE, have
issued Trust Preference Securities,
which are listed on the New York
Stock Exchange.
Inquiries may also
be directed to:
EQ Shareowner Services
1110 Centre Point Curve, Suite 101
Mendota Heights, MN 55120-4100
Fax:
(651) 450-4033
EQ Shareowner Services
www.shareowneronline.com
Investor Relations
www.edisoninvestor.com
Email: invrel@edisonintl.com
Phone: (877) 379-9515
Online account information:
www.shareowneronline.com
Dividend Reinvestment and
Direct Stock Purchase Plan
A prospectus and enrollment forms
for Edison International’s common
stock Dividend Reinvestment and
Direct Stock Purchase Plan are
available from EQ Shareowner
Services upon request.
Transfer Agent and Registrar
Equiniti Trust Company (EQ), which
maintains shareholder records,
is the transfer agent and registrar
for Edison International’s common
stock and Southern California Edison
Company’s preference stock. Share-
holders may call EQ Shareowner
Services, (800) 347-8625, between
7 a.m. and 7 p.m. (Central Time),
Monday through Friday, to speak
with a representative (or to use
the interactive voice response unit
24 hours a day, seven days a
week) regarding:
n stock transfer and name-change
requirements;
n address changes, including dividend
payment addresses;
n electronic deposit of dividends;
n taxpayer identification number
submissions or changes;
n duplicate 1099 and W-9 forms;
n notices of, and replacement of,
destroyed stock certificates and
dividend checks;
n Edison International’s Dividend
Reinvestment and Direct
Stock Purchase Plan, including
enrollments, purchases,
withdrawals, terminations,
transfers, sales, duplicate
statements and direct debit
of optional cash for dividend
reinvestment; and
n requests for access to online
account information.
2244 Walnut Grove Avenue
Rosemead, CA 91770
www.edison.com
Edison International and
Southern California Edison
2020 Annual Report
2/26/21 12:34 AM