2244 Walnut Grove Avenue
Rosemead, CA 91770
www.edison.com
Modernizing the Power Network
Edison International and Southern California Edison
2015 Annual Report
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2015 FINANCIAL HIGHLIGHTS
Dollar amounts in millions, except per-share data
Years ended December 31,
Operating revenue
Core earnings (1)
Less: non-core items:
2015
2014
2013
$11,524 $13,413 $12,581
$1,237
$1,497
$1,336
Write-down, impairment and other charges
Discontinued operations
Other items
Total non-core items
Basic earnings(1)
Core earnings per share (1)
Basic earnings per share (1)
(382)
36
35
7
31
115 (322)
(316)
$915
$1,612
$1,020
$4.10
$3.80
$4.59
$3.13 $4.95 $2.81
(72) (365)
185
2
Total assets at December 31
Dividends paid per common share
Total shareholder return
Total employees
$50,310 $49,734 $46,225
$1.35
$1.42
$1.67
(6.9)% 45.0% 5.4%
13,677
13,690
12,768
BUSINESS HIGHLIGHTS
Southern California Edison
Rate base (2)
Capital expenditures (2)
Peak demand (megawatts)
Total system sales (kilowatt-hours, in millions)
$24,596
$3,867
23,079
87,544
$23,254 $21,116
$3,530
$3,967
22,534
23,055
87,397
88,986
(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 December 31, which includes capital expenditures related to certain FERC-approved
projects during the construction phase and excludes San Onofre Nuclear Generating Station. Capital expenditures for each year
include accruals.
Inquiries may also be directed to:
Wells Fargo Shareowner Services
1110 Centre Point Curve, Suite 101
Mendota Heights, MN 55120-4100
Fax:
(651) 450-4033
Wells Fargo Shareowner ServicesSM
www.shareowneronline.com
Investor Relations
www.edisoninvestor.com
Email: invrel@sce.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 Wells Fargo Shareowner
Services upon request
EDISON INTERNATIONAL
Annual Meeting
The annual meeting of shareholders
will be held on Thursday, April 28,
2016, at 9:00 a.m., Pacific Time, at
the Hilton Los Angeles San Gabriel
Hotel, 225 West Valley Boulevard,
San Gabriel, California 91776.
Corporate Governance Practices
A description of Edison International’s
corporate governance practices is
available on our Web site at
www.edisoninvestor.com. The Edison
International Board Nominating/
Corporate Governance Committee
periodically reviews the Company’s
corporate governance practices and
makes recommendations to the
Company’s Board that the practices
be updated from time to time.
Stock Listing and Trading Information
Common Stock: The New York Stock
Exchange uses the ticker symbol EIX;
daily newspapers list the stock as
EdisonInt.
SCE’s 4.08%, 4.24%, 4.32% and
4.78% Series of $25 par value
cumulative preferred stock are listed
on the NYSE MKT stock exchange.
Shares of SCE’s preference stock are
not listed on an exchange. SCE Trust I,
SCE Trust II, SCE Trust III and SCE
Trust IV, subsidiaries of SCE, have
issued Trust Preference Securities
which are listed on the New York
Stock Exchange.
Transfer Agent and Registrar
Wells Fargo Bank, N.A., which maintains
shareholder records, is the transfer
agent and registrar for Edison
International’s common stock and
Southern California Edison Company’s
preferred and preference stock.
Shareholders may call Wells Fargo
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.
Edison International and Southern California Edison 2015 Annual Report
Page 1
Letter to Shareholders
My shareholder letters have consistently emphasized the transformative
change we see occurring in our industry and our strategy for thriving in
this new environment. Even so, our core mission remains unchanged: safely
providing reliable, affordable, and clean electric service to our customers.
Delivering on that mission is how we create value for shareholders.
Our strategy has three themes:
1) Operational and service excellence. Operate
our existing business with a focus on controlling
costs and customer rates and improving service to
our utility customers.
2) Build the 21st century power network. Invest in
our existing business and manage unprecedented
changes in policy and technology.
3) Expand growth potential. Systematically explore
new growth opportunities by making disciplined
investments in new businesses where industry
changes are producing unmet customer need,
where we believe Edison has competitive advantages,
and where attractive, scalable opportunities exist
for new growth.
For each of these three strategic areas, I will describe
the progress made in 2015 and our plans for 2016
and beyond.
Starting with operational and service excellence at
Southern California Edison (SCE), we continued to
improve efficiency and reduce overhead cost as
well as benefit from lower fuel and purchased power
costs. As a result, our customers will on average
enjoy a reduction in rates of 8 percent in 2016 from
2015 levels. This is a major benefit for our customers
and something we are proud to deliver to them.
In 2015, core earnings were $4.10 per share and our
GAAP earnings were $3.13 per share. (See opposite
page for a reconciliation of core and GAAP earnings.)
These results compared to 2014 earnings of $4.59
and $4.95 per share, respectively.
Reflecting the softness in the overall stock market
and energy stocks in particular, Edison International’s
stock price closed 2015 down 9.6 percent. Our stock
slightly outperformed our primary benchmark, the
Philadelphia Utilities Index, which fell 9.8 percent in
2015. The S&P 500 Index declined 0.7 percent.
In December, we increased our dividend for the
twelfth consecutive year to an annual rate of
$1.92 per share – a 15 percent increase. This was
the second year of double-digit increases in the
dividend, and reflected our commitment to returning
our dividend in steps over time to our target payout
ratio of 45 to 55 percent of SCE’s earnings.
With our San Onofre Nuclear Generating Station
(SONGS), we continue to work our way through
lingering legal and procedural challenges to the
settlement agreement, which was unanimously
approved in late 2014 by the California Public Utilities
Commission (CPUC). That agreement settled all
cost recovery issues surrounding our closing of
SONGS. Many of its provisions, which resulted in rate
reduction benefits to customers, have already been
implemented. The Commission reached decisions on
some of the challenges to the agreement, while
others remain outstanding.
Edison International and Southern California Edison 2015 Annual Report
Page 2
In October, we reported a $400 million settlement
with Nuclear Electric Insurance Limited on insurance
claims related to the shutdown of SONGS. The
agreement settled all insurance claims by the three
owners of San Onofre related to the outage caused
by the failure of the plant’s replacement steam
generators. After covering legal costs, 95 percent
of SCE’s share of the remaining recovery will be
allocated to customers as a reduction in purchased
power costs and 5 percent to the company.
The larger claim against Mitsubishi Heavy Industries
for the failed design of the SONGS replacement
steam generators continues to proceed under binding
arbitration through the International Chamber of
Commerce. We expect a decision by late 2016.
Turning to our second strategic theme, in November
the CPUC approved SCE’s General Rate Case, which
establishes a significant portion of customer rates for
the years 2015-2017. The CPUC’s final decision
supported SCE’s objectives of increasing infrastructure
investments to enhance reliability and safety. This
decision is consistent with our expectation of 7 percent
compound average growth in rate base through 2017.
On July 1, SCE filed with the CPUC its Distribution
Resources Plan (DRP), which outlined proposed
investments in the grid necessary to accommodate
growth in distributed energy resources such as
rooftop solar and electric vehicles. The DRP outlined
several areas of the distribution grid requiring
modernization, including a digital communications
network, installing more digital monitoring and control
devices, introducing more automated functions, and
enhancing voltage control and fault protection.
There are issues to be weighed concerning the cost
and pace of implementation of building a flexible grid
as outlined in the DRP. However, we expect SCE to
be able to incorporate grid modernization elements
into its 2018 to 2020 General Rate Case, which we
will file in the fall of 2016.
We eagerly look forward to advancing our strategy
and growing our existing business in 2016. California
legislation passed last year will increase the target
for renewable power to 50 percent of delivered
energy by 2030. Our strategy of building the clean
energy grid of the future is aligned with this law. It
also provides legislative support for utility investment
in transportation electrification, which we view as a
long-term growth opportunity for SCE. We see
investments in electric vehicle charging infrastructure
and energy storage as complements to SCE’s wires-
focused strategy.
Our third strategic effort involves expanding our
growth potential.
As the electric industry becomes increasingly
technologically complex and more impacted by
environmental, regulatory, and legal pressures, we
become more certain that changes will occur in the
regulated utility model. It is impossible to predict
the precise direction, magnitude, or pace of these
changes. However, we believe it is prudent to adopt
the planning assumptions that the changes will be
more substantive, the pace more rapid, and that
California will be an early test bed.
For our company, we see more opportunities for
growth than threats in these changes. Our market
research has led us to conclude that the largest
commercial and industrial customers with nationwide
footprints are underserved nationally and struggle to
deal locally with many different utilities, tariffs, and
new technologies. We believe we possess several
competitive advantages to succeed with customers
in this new and quickly evolving power environment.
Our roots are as developers, operators, and investors
in complex infrastructure. We have deep technical,
commercial, and regulatory experience and knowledge
of the power system. Our brand and substantial
balance sheet can be relied upon by customers and
contrasts with the dizzying array of untested start-ups.
We are focused on finding those areas where
customer needs are unmet, that match well with our
competitive advantages, and that hold promise for
scaling-up sufficiently. Edison Energy Group continues
Edison International and Southern California Edison 2015 Annual Report
Page 3
to expand into businesses that meet this profile,
including distributed solar generation, energy services
for commercial and industrial customers, providing
new sources of water, and competitive transmission.
Our SoCore Energy subsidiary added more commercial
rooftop solar customers in 2015, and now has nearly
250 projects operating in 16 states. It has expanded
beyond rooftop installations to ground-mounted
community solar and rural electric cooperative projects.
SoCore also piloted an innovative project for Cinemark
Theaters that combined its rooftop solar panels with
battery storage from Tesla Energy.
We continue to build out an integrated energy services
platform to address the needs of commercial and
industrial customers. Our platform was expanded
through recent acquisitions in the areas of energy
engineering and consulting, energy procurement
advisory services, and sourcing off-site renewable
energy. In a complementary move, Edison Energy
Group recently launched Edison Water Resources to
focus on providing new sources of clean water for
commercial, industrial, and institutional customers
through smaller, distributed projects.
Today, these new businesses are small, even though
we think the opportunities could be significant. The
vast majority of our capital today is focused on our
core business – modernizing the electric grid at
SCE and moving up our dividend payout ratio closer
to the industry norm. Our approach to these new
businesses will be disciplined: focused on small
initial investments to understand strategic fit, profit
drivers, and scalability. We have allocated some
capital to testing and building our new businesses,
but it is currently only around 1 to 2 percent of total
capital deployed.
We are gaining confidence that there is indeed a
market need for these new businesses and that they
can be profitable. The major question is whether
these businesses can be scaled-up sufficiently to be
significant to a company our size. If performance
warrants and the opportunities continue to look
sizeable, we are in the position to increase our
commitment. We are encouraged, but ultimately
we will be driven by results.
Much of our success relies on the talent and
commitment of our employees, executive leadership,
and our Board of Directors. I want to especially
welcome our newest director, William P. Sullivan.
Bill is the recently retired CEO of Agilent Technologies,
with significant experience in Silicon Valley and
meeting the challenges of rapid technological change
and industry transformation. I am also pleased to
welcome James T. Morris, who has been nominated
by the Board for election at the annual meeting. Jim is
the current chairman, president and CEO of Pacific
Life Insurance, a company with over $8 billion in
revenue that operates in a highly regulated environment
and is headquartered in Southern California.
We believe we can grow Edison International by
creating a modern grid that both supports the policy
objective of moving to a low carbon economy and
improves the flexibility, reliability, and affordability of
the electric system. We at Edison International are
eager to provide the creative leadership needed to
tackle these challenges, and in so doing serve our
customers and communities, and build value for
our shareholders.
Theodore F. Craver, Jr.
Chairman, President and Chief Executive Officer
February 25, 2016
Edison International and Southern California Edison 2015 Annual Report
Page 4
Sierra Crest is a Zero Net Energy
community.
Helping Make Zero Net Energy Homes a Reality
The state of California is mandating all new residential construction to achieve Zero Net Energy
(ZNE) performance by 2020. A ZNE building produces as much energy as it consumes over the
course of a year. The state’s first ZNE residential community, Sierra Crest in Fontana, is the
product of a partnership between the homebuilder Meritage Homes, SCE, and industry and
government organizations. Some of the features in ZNE homes include high-efficiency solar panels,
heat pumps for space heating, cooling, and hot water, spray foam insulation, highly efficient windows,
LED lighting, energy storage, smart appliances and home energy management systems.
The Coronado family moved into their Zero Net Energy home in Fontana, Calif., in December 2015. Edison International and Southern California Edison 2015 Annual Report
Page 5
Solar panels on
carport roofs.
Retrofitting Multifamily Communities to Save Energy
The Village at Beechwood, a low-income apartment community in Lancaster, Calif., operated
by nonprofit LINC Housing Corp., is implementing energy upgrades with the help of rebates
administered by SCE. The $2.46 million project includes engineering, research and construction
for energy-efficiency upgrades and renewable energy. Improvements included the addition
of a solar water heating system and the installation of an 84-kilowatt rooftop solar system
on the community’s carport roofs. The retrofits included energy-efficient appliances, sealing
ductwork and the addition of insulation. Programs also help residents better manage their
energy usage.
Brandy and her daughter Brooklyn, residents of the Village at Beechwood in Lancaster, Calif., enjoy the community center. Edison International and Southern California Edison 2015 Annual Report
Page 6
S Bravo’s thermal
oxidizer system.
Partnering with Industrial Customers for Energy Efficiency
S Bravo Systems Inc. is a woman-owned manufacturer of containment systems for fuel
handling in the petroleum industry, with facilities in Commerce, Calif. S Bravo was founded
by company president Paola Bravo’s father, Sergio Bravo, who invented and patented the
“Bravo Box” to protect against soil and groundwater contamination. Working with SCE,
S Bravo upgraded its facility to reduce overall electricity consumption and improve operations.
S Bravo installed a variable frequency drive motor to increase the efficiency of its regenerative
thermal oxidizer system, among other improvements. These steps resulted in energy savings
of more than 716,000 kilowatt hours.
Paola Bravo, president of S Bravo Systems, and her father Sergio Bravo, the company’s founder. Edison International and Southern California Edison 2015 Annual Report
Page 7
Cody Vaughan, regional
administrative assistant to the
regional manager of Cinemark
USA Inc., at Cinemark’s movie
theater in Orange, Calif.
Tesla Energy lithium ion batteries.
Serving Commercial Customers with Innovative Technology
Edison International’s SoCore Energy subsidiary recently completed a battery storage project at
the Cinemark movie theater in Orange, Calif. This is the first of two energy storage projects that
Cinemark and SoCore have partnered on to-date. The two companies have also implemented
a 5-megawatt portfolio of photovoltaic solar together on theater rooftops in California, New York,
Texas and Utah. The energy storage system uses Tesla Energy’s lithium ion batteries, inverters and
control software. The battery’s intelligent control platform is designed to reduce the theater’s peak
demand and lower its demand charges. Distributed battery storage projects also convey broader,
system-wide benefits because they improve the overall efficiency of the electric grid.
Edison International and Southern California Edison 2015 Annual Report
Page 8
Our Vision
Leading the Way in Electricity SM
Our Values
Integrity
Excellence
Respect
Continuous Improvement
Teamwork
Our Shared Enterprise
Together we provide an indispensable service that
powers society. We are a single enterprise that is
stronger than the sum of its parts.
Our Operating Priorities
We operate safely
We meet customer needs
We value diversity
We build productive partnerships
We protect the environment
We learn from experience and improve
We grow the value of our business
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, 2015
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
1-2313
Exact Name of Registrant
as specified in its charter
State or Other Jurisdiction of
Incorporation or Organization
IRS Employer
Identification Number
EDISON INTERNATIONAL
SOUTHERN CALIFORNIA EDISON COMPANY
California
California
95-4137452
95-1240335
EDISON INTERNATIONAL
2244 Walnut Grove Avenue
(P.O. Box 976)
Rosemead, California 91770
(Address of principal executive offices)
SOUTHERN CALIFORNIA EDISON COMPANY
2244 Walnut Grove Avenue
(P.O. Box 800)
Rosemead, California 91770
(Address of principal executive offices)
(626) 302-2222
(Registrant's telephone number, including area code)
(626) 302-1212
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Name of each exchange on which registered
Edison International: Common Stock, no par value
Southern California Edison Company: Cumulative Preferred Stock
4.08% Series, 4.24% Series, 4.32% Series, 4.78% Series
NYSE LLC
NYSE MKT LLC
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 and posted on its corporate website, if any, every Interactive Data File required to be
submitted and posted 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 and post such files).
Edison International
Yes
No
Southern California Edison Company
Yes
No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of
registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.
Edison International
Southern California Edison Company
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See
the definitions of "accelerated filer," "large accelerated filer," and "smaller reporting company" in Rule 12b-12 of the Exchange Act. (Check One):
Edison International
Large Accelerated Filer
Accelerated Filer
Non-accelerated Filer
Smaller Reporting Company
Southern California Edison Company Large Accelerated Filer
Accelerated Filer
Non-accelerated Filer
Smaller Reporting 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, 2015, the last business day of the most
recently completed second fiscal quarter:
Edison International
Southern California Edison Company Wholly owned by Edison International
Approximately $18.1 billion
Common Stock outstanding as of February 19, 2016:
Edison International
Southern California Edison Company
325,811,206 shares
434,888,104 shares (wholly owned by Edison International)
Designated portions of the Proxy Statement relating to registrants' joint 2016 Annual Meeting of Shareholders have been incorporated by reference into the parts of
this report where indicated.
DOCUMENTS INCORPORATED BY REFERENCE
SEC Form 10-K
Reference Number
Part II, Item 7
TABLE OF CONTENTS
GLOSSARY ..............................................................................................................................
FORWARD-LOOKING STATEMENTS...............................................................................
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS.......................................................................................
MANAGEMENT OVERVIEW ..............................................................................................
Highlights of Operating Results.......................................................................................
Electricity Industry Trends ..............................................................................................
Capital Program................................................................................................................
Edison International Dividend Policy .............................................................................
Regulatory Proceedings ....................................................................................................
Permanent Retirement of San Onofre and San Onofre OII Settlement ......................
RESULTS OF OPERATIONS ................................................................................................
Southern California Edison Company ............................................................................
Revenue Impact of 2015 GRC Decision.....................................................................
Utility Earning Activities.............................................................................................
Utility Cost-Recovery Activities...................................................................................
Supplemental Operating Revenue Information.........................................................
Income Taxes...............................................................................................................
Edison International Parent and Other ..........................................................................
Loss from Continuing Operations..............................................................................
Income from Discontinued Operations (Net of Tax) .................................................
LIQUIDITY AND CAPITAL RESOURCES.........................................................................
Southern California Edison Company ............................................................................
Bonus Depreciation ....................................................................................................
Available Liquidity ......................................................................................................
Capital Investment Plan – Major Transmission Projects..........................................
Decommissioning of San Onofre ...............................................................................
SCE Dividends ............................................................................................................
Margin and Collateral Deposits .................................................................................
Regulatory Balancing Accounts .................................................................................
Edison International Parent and Other ..........................................................................
EME Settlement Agreement .......................................................................................
Edison Energy Group Capital Expenditures .............................................................
Historical Cash Flows .......................................................................................................
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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..............................................................................................
Income Taxes .....................................................................................................................
Nuclear Decommissioning – Asset Retirement Obligation............................................
Pensions and Postretirement Benefits Other than Pensions .........................................
Accounting for Contingencies ..........................................................................................
NEW ACCOUNTING GUIDANCE .......................................................................................
RISK FACTORS ......................................................................................................................
RISKS RELATING TO EDISON INTERNATIONAL ........................................................
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY ...................
Regulatory Risks ...............................................................................................................
Financing Risks .................................................................................................................
Competitive and Market Risks ........................................................................................
Operating Risks.................................................................................................................
Cybersecurity Risks ..........................................................................................................
Environmental Risks.........................................................................................................
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK .....
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA ........................................
REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM .........
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.........
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Part I, Item 1A
Part II, Item 7A
Part II, Item 8
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. Income Taxes .......................................................................................................
Note 8. Compensation and Benefit Plans .......................................................................
Note 9. Investments ..........................................................................................................
Note 10. Regulatory Assets and Liabilities......................................................................
Note 11. Commitments and Contingencies .....................................................................
Note 12. Preferred and Preference Stock of Utility........................................................
Note 13. Accumulated Other Comprehensive Loss........................................................
Note 14. Interest and Other Income and Other Expenses.............................................
Note 15. Discontinued Operations ...................................................................................
Note 16. Supplemental Cash Flows Information............................................................
Note 17. Related-Party Transactions...............................................................................
Note 18. Quarterly Financial Data (Unaudited).............................................................
SELECTED FINANCIAL DATA............................................................................................
CONTROLS AND PROCEDURES .......................................................................................
OTHER INFORMATION .......................................................................................................
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE ............................................................
BUSINESS.................................................................................................................................
CORPORATE, STRUCTURE, INDUSTRY AND OTHER INFORMATION ..................
Subsidiaries of Edison International ...............................................................................
Regulation of Edison International as a Holding Company .........................................
Employee and Labor Relations........................................................................................
Insurance............................................................................................................................
SOUTHERN CALIFORNIA EDISON COMPANY .............................................................
Regulation ..........................................................................................................................
Overview of Ratemaking Process ....................................................................................
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iii
Part II, Item 6
Part II, Item 9A
Part II, Item 9B
Part II, Item 9
Part I, Item 1
Purchased Power and Fuel Supply ..................................................................................
Competition .......................................................................................................................
Properties ...........................................................................................................................
Seasonality .........................................................................................................................
ENVIRONMENTAL REGULATION OF EDISON INTERNATIONAL AND
SUBSIDIARIES........................................................................................................................
Air Quality .........................................................................................................................
Water Quality ....................................................................................................................
Greenhouse Gas Regulation .............................................................................................
UNRESOLVED STAFF COMMENTS ..................................................................................
PROPERTIES ..........................................................................................................................
LEGAL PROCEEDINGS........................................................................................................
Shaver Lake Dam Liner Permit Violation Proceeding ..................................................
EXECUTIVE OFFICERS OF EDISON INTERNATIONAL .............................................
EXECUTIVE OFFICERS OF SOUTHERN CALIFORNIA EDISON COMPANY.........
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE............
EXECUTIVE COMPENSATION ..........................................................................................
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT AND RELATED STOCKHOLDER MATTERS....................................
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR
INDEPENDENCE ....................................................................................................................
PRINCIPAL ACCOUNTANT FEES AND SERVICES........................................................
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED
STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY
SECURITIES............................................................................................................................
Purchases of Equity Securities by Edison International and Affiliated Purchasers...
Purchases of Equity Securities by Southern California Edison Company and
Affiliated Purchasers ........................................................................................................
Comparison of Five-Year Cumulative Total Return......................................................
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES .............................................
SIGNATURES ..........................................................................................................................
EXHIBIT INDEX .....................................................................................................................
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Part I, Item 1B
Part I, Item 2
Part I, Item 3
Part I, Item 3
Part I, Item 3
Part III, Item 10
Part III, Item 11
Part III, Item 12
Part III, Item 13
Part III, Item 14
Part II, Item 5
Part IV, Item 15
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.
iv
GLOSSARY
The following terms and abbreviations appearing in the text of this report have the meanings indicated below.
Amended Plan of
Reorganization...................
EME Chapter 11 Bankruptcy Plan of Reorganization as amended to incorporate the terms of
the Settlement Agreement, dated February 19, 2014
AFUDC..............................
APS....................................
ARO(s) ..............................
Bankruptcy Code ...............
Bankruptcy Court ..............
Bcf .....................................
Bonus depreciation ............
CAA...................................
CAISO ...............................
CARB ................................
Competitive Businesses.....
CPUC.................................
CRRs..................................
DOE...................................
Edison Energy....................
Edison Energy Group ........
EME...................................
EME Settlement
Agreement .........................
EMG ..................................
allowance for funds used during construction
Arizona Public Service Company, operator of Four Corners
asset retirement obligation(s)
Chapter 11 of the United States Bankruptcy Code
United States Bankruptcy Court for the Northern District of Illinois, Eastern Division
billion cubic feet
Current federal tax deduction of a percentage of the qualifying property placed in service
during periods permitted under tax laws
Clean Air Act
California Independent System Operator
California Air Resources Board
businesses focused on providing energy services, including distributed generation and/or
storage, to commercial and industrial customers; engaging in competitive transmission
opportunities; and exploring distributed water treatment and recycling.
California Public Utilities Commission
congestion revenue rights
U.S. Department of Energy
Edison Energy, LLC, a wholly-owned subsidiary of Edison Energy Group and one of the
Competitive Businesses
Edison Energy Group, Inc., the holding company for the Competitive Businesses
Edison Mission Energy
Settlement Agreement by and among Edison Mission Energy, Edison International and the
Consenting Noteholders identified therein, dated February 18, 2014
Edison Mission Group Inc., a wholly owned subsidiary of Edison International and the
parent company of EME and Edison Capital
EPS ....................................
ERRA.................................
FERC .................................
Four Corners......................
earnings per share
energy resource recovery account
Federal Energy Regulatory Commission
coal fueled electric generating facility located in Farmington, New Mexico in
GAAP ................................
GHG ..................................
GRC...................................
GWh ..................................
HLBV ................................
IRS.....................................
Joint Proxy Statement........
which SCE held a 48% ownership interest
generally accepted accounting principles
greenhouse gas
general rate case
gigawatt-hours
hypothetical liquidation at book value
Internal Revenue Service
Edison International's and SCE's definitive Proxy Statement to be filed with the SEC in
connection with Edison International's and SCE's Annual Shareholders' Meeting to be held
on April 28, 2016
MD&A............................... Management's Discussion and Analysis of Financial Condition and Results
of Operations in this report
MHI ................................... Mitsubishi Heavy Industries, Inc. and related companies
Moody's ............................. Moody's Investors Service
MW....................................
MWh..................................
NAAQS .............................
NEIL ..................................
megawatts
megawatt-hours
national ambient air quality standards
Nuclear Electric Insurance Limited
v
NEM ..................................
NERC ................................
NRC...................................
ORA...................................
OII......................................
Palo Verde..........................
PBOP(s).............................
PG&E ................................
QF(s)..................................
ROE ...................................
S&P....................................
San Onofre.........................
San Onofre OII Settlement
Agreement .........................
SCE....................................
SDG&E..............................
SEC....................................
SED....................................
SoCalGas ...........................
TURN ................................
US EPA..............................
VIE(s) ................................
net energy metering
North American Electric Reliability Corporation
Nuclear Regulatory Commission
CPUC's Office of Ratepayers Advocates
Order Instituting Investigation
nuclear electric generating facility located near
Phoenix, Arizona in which SCE holds a 15.8% ownership interest
postretirement benefits other than pension(s)
Pacific Gas & Electric Company
qualifying facility(ies)
return on common equity
Standard & Poor's Ratings Services
retired nuclear generating facility located in south
San Clemente, California in which SCE holds a 78.21% ownership interest
Settlement Agreement by and among The Utility Reform Network, the CPUC's Office of
Ratepayer Advocates, SDG&E, the Coalition of California Utility Employees, and Friends of
the Earth, dated November 20, 2014
Southern California Edison Company
San Diego Gas & Electric
U.S. Securities and Exchange Commission
Safety and Enforcement Division of the CPUC, formerly known as the Consumer Protection
and Safety Division or CPSD
Southern California Gas Company
The Utility Reform Network
U.S. Environmental Protection Agency
variable interest entity(ies)
vi
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 statement that does 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 of 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 in a timely manner from its customers through regulated rates, including regulatory
assets related to San Onofre;
• decisions and other actions by the CPUC, the FERC, the NRC and other regulatory authorities, including determinations
of authorized rates of return or return on equity, and delays in regulatory actions;
• ability of Edison International or SCE to borrow funds and access the capital markets on reasonable terms;
• possible customer bypass or departure due to technological advancements in the generation, storage, transmission,
distribution and use of electricity, and supported by public policy, government regulations and incentives;
•
risks inherent in the construction of transmission and distribution infrastructure replacement and expansion projects,
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), and governmental approvals;
•
risks associated with the operation of transmission and distribution assets and power generating facilities including: public
safety issues, failure, availability, efficiency, and output of equipment and availability and cost of spare parts;
•
risks associated with the retirement and decommissioning of nuclear generating facilities;
• physical security of SCE's critical assets and personnel and the cyber security of SCE's critical information technology
systems for grid control, and business and customer data;
• ability of Edison International to develop its Competitive Businesses, manage new business risks, and recover and earn a
return on its investment in newly developed or acquired businesses;
• cost and availability of electricity, including the ability to procure sufficient resources to meet expected customer needs in
the event of power plant outages or significant counterparty defaults under power-purchase agreements;
• environmental laws and regulations, at both the state and federal levels, or changes in the application of those laws, that
could require additional expenditures or otherwise affect the cost and manner of doing business;
• 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 CAISO, WECC, NERC, and adjoining regions;
• 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;
• ability to obtain sufficient insurance, including insurance relating to SCE's nuclear facilities and wildfire-related liability,
and to recover the costs of such insurance or in the absence of insurance the ability to recover uninsured losses;
• potential for penalties or disallowance for non-compliance with applicable laws and regulations;
1
• cost and availability 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; and
• weather conditions and natural disasters.
See "Risk Factors" in this report for additional information on risks and uncertainties that could cause results to differ from
those currently expected or that otherwise could impact Edison International, SCE or their subsidiaries.
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 risk, 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. Additionally, Edison International and SCE provide direct links to SCE's regulatory
filings with the CPUC and the FERC in open proceedings most important to investors at www.edisoninvestor.com (SCE
Regulatory Highlights) so that such filings are available to all investors upon SCE filing with the relevant agency.
Except when otherwise stated, references to each of Edison International, SCE, EMG, Edison Energy Group, EME or Edison
Capital 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.
2
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
MANAGEMENT OVERVIEW
Highlights of Operating Results
Edison International is the parent holding company of SCE. SCE is a public utility primarily engaged in the business of
supplying and delivering electricity to an approximately 50,000 square mile area of southern California. Edison International
is also the parent company of subsidiaries that are engaged in competitive businesses focused on providing energy services to
commercial and industrial customers, including distributed resources, engaging in transmission opportunities, and exploring
distributed water treatment and recycling (the "Competitive Businesses"). Such business activities are currently not material
to report as a separate business segment. 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. Unless otherwise described, all of the information contained in this annual report relates to
both filers.
(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
Write-down, impairment and other charges
NEIL insurance recoveries
Edison International Parent and Other
Gain on sale of Beaver Valley lease interest
Edison Capital sale of affordable housing portfolio
Income from allocation of losses to tax equity investor
Discontinued operations
Total non-core items
Core earnings (losses)
SCE
Edison International Parent and Other
Edison International
2015
2014
2015 vs 2014
Change
2013
$
$
998
(13)
35
1,020
$
1,453
(26)
185
1,612
(455) $
13
(150)
(592)
(382)
12
—
10
9
35
(316)
(72)
—
—
—
2
185
115
(310)
12
—
10
7
(150)
(431)
900
(21)
36
915
(365)
—
7
—
—
36
(322)
1,368
(32)
1,336
$
1,525
(28)
1,497
$
$
(157)
(4)
(161) $
1,265
(28)
1,237
Edison International's earnings are prepared in accordance with GAAP used in the United States. Management uses core
earnings 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 income or loss from discontinued operations, income resulting from allocation of losses to tax equity
investor under the HLBV accounting method and income or loss from significant discrete items that management does not
consider representative of ongoing earnings, such as: exit activities, including sale of certain assets and other activities that
are no longer continuing; write downs, asset impairments and other charges related to certain tax, regulatory or legal
settlements or proceedings.
SCE's 2015 core earnings decreased $157 million for the year primarily from lower CPUC-related revenue which reflects the
implementation of the 2015 CPUC General Rate Case decision partially offset by an increase in FERC-related revenue from
rate base growth, lower operation and maintenance and earnings on funds used during construction.
3
In addition, income tax benefits were lower in 2015. During 2015, SCE recorded $100 million of income tax benefits from
revisions to liabilities for uncertain tax positions for tax years 2010 through 2012. These benefits were partially offset by
changes in estimated taxes related to net operating loss carrybacks, interest and state income taxes. During 2014, SCE
recorded $133 million of income tax benefits from incremental repair deductions and $29 million of income tax benefits from
revisions to liabilities for uncertain tax positions.
Consolidated non-core items for 2015 and 2014 for Edison International included:
• Write-down of $382 million in 2015 of regulatory assets previously recorded for recovery of deferred income taxes from
2012 – 2014 incremental tax repair deductions. For further information, see "—Regulatory Proceedings—2015 General
Rate Case."
•
•
•
•
•
Income of $20 million ($12 million after-tax) in 2015 related to shareholder's portion of NEIL insurance recoveries arising
from the outage and shutdown of the San Onofre Units 2 and 3 generating stations and the recovery of legal costs. For
further information, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—San
Onofre Related Matters."
Income of $16 million ($10 million after-tax) in 2015 related to completion of the sale of Edison Capital's affordable
housing investment portfolio which represents the exit from this business activity.
Impairment and other charges of $163 million ($72 million after-tax) in 2014 related to the San Onofre OII Settlement
Agreement For further information, see "—Permanent Retirement of San Onofre and San Onofre OII Settlement" and
"Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Impairment of
Long-Lived Assets."
Income of $9 million and $2 million for 2015 and 2014, respectively, related to losses allocated to tax equity investors
under the HLBV accounting method. For further information, see "Notes to Consolidated Financial Statements—Note 1.
Summary of Significant Accounting Policies." Edison International reflected in core earnings the operating results of the
solar rooftop projects and their related financings, including the priority returns to tax equity investors. The losses
allocated to the tax equity investor under HLBV method results in income allocated to subsidiaries of Edison
International, neither of which is due to the performance of the projects but rather due to the allocation of income tax
attributes under the tax equity financing. Accordingly, Edison International has included the non-operating allocation of
income as a non-core item. For further information on HLBV, see the "Notes to Consolidated Financial Statements—
Note 1. Summary of Significant Accounting Policies."
Income from discontinued operations, net of tax, was $35 million for 2015 primarily due to income tax benefits (from
revised estimates based on filing of the 2014 tax returns) and insurance recoveries. The 2014 income was related to the
impact of completing the transactions called for in the EME Settlement Agreement and income tax benefits from
resolution of uncertain tax positions and other impacts related to EME. See "Notes to Consolidated Financial Statements
—Note 7. Income Taxes" for further information.
See "Results of Operations" for discussion of SCE and Edison International Parent and Other results of operations, including
a comparison of 2014 results to 2013.
Electricity Industry Trends
The electricity industry is undergoing change, including technological advancements such as customer-owned generation and
energy storage that could alter the nature of energy generation and delivery. Recent trends in the electric industry include:
•
•
•
•
leveling of demand due to slower population growth, demand side management of energy and an increase in customer-
owned generation;
public policy initiatives to reduce GHG emissions and encourage competition for the sale and delivery of electricity;
increased need for infrastructure replacement and grid development to accommodate new technologies; and
technological and financing innovation that facilitate conservation, distributed energy resources, such as customer-owned
generation and energy storage, and changes in electricity generation, transmission and distribution.
4
SCE is investing in and strengthening its electric grid and driving operational and service excellence to improve system
safety, reliability and service while controlling costs and rates.
The electric distribution grid is an important component of California's public policy goals to support a cleaner environment.
These policy goals continue to advance as California moves forward in implementing Senate Bill 350. SB 350 requires retail
sellers of electricity to procure 50% of their customers' electricity requirements from renewable resources by 2030.
California policy goals also promote an increase in electric vehicle usage and investment in charging infrastructure. These
goals may create opportunities for the electric grid to enable GHG emission reductions by providing the supporting
infrastructure to increase adoption of customer-owned generation, electric storage, and electric vehicles but they may increase
customer rates and add technical complexity and risk to the safe and reliable operation of the electric grid.
In 2015, SCE filed a Distribution Resources Plan (“DRP”) with the CPUC as part of the CPUC's initiative to address, among
other issues, the increased penetration of customer-owned generation and other distributed energy resources, such as rooftop
solar. For more information, see "—Capital Program—Distribution Grid Development—Distribution Resources Plan" below.
Edison International is also investing in Competitive Businesses. These include small, targeted investments in energy service
companies that utilize technologies and access markets to capitalize on the changes in the electric industry. Current areas of
focus are providing energy services to commercial and industrial customers, including distributed resources, engaging in
competitive transmission opportunities, and exploring distributed water treatment and recycling.
Capital Program
SCE forecasts capital expenditures for 2016 – 2017 in the range of $8.0 billion to $8.3 billion. The forecast includes the level
of spending authorized in the 2015 GRC decision. The low end of the range reflects a 3% reduction from forecasted levels for
FERC projects using management judgment based on historical experience. Total capital expenditures (including accruals),
were $3.9 billion in 2015 and $4.0 billion in 2014. SCE's year-end rate base (excluding San Onofre) was $24.6 billion at
December 31, 2015 compared to $23.3 billion at December 31, 2014.
SCE's 2015 actual capital expenditures (including accruals) and the 2016 – 2017 forecast for major capital expenditures are
set forth in the table below:
(in millions)
Transmission
Distribution
Generation
Total estimated capital expenditures
Total estimated capital expenditures for 2016 – 2017 (using the range
discussed above)
2015
Actual
2016
2017
2016 – 2017
Total
$
$
613 $
704 $
3,028
226
3,867 $
3,113
250
4,067 $
1,195 $
2,831
173
4,199 $
1,899
5,944
423
8,266
$
3,980 $
4,059 $
8,039
Capital expenditures for projects under CPUC jurisdiction are recovered through the authorized revenue requirement in
SCE's GRCs or through other CPUC-authorized mechanisms. Recovery for 2016 – 2017 planned expenditures for projects
under FERC jurisdiction will be pursued through FERC-authorized mechanisms. SCE is scheduled to file its 2018 GRC
application in September 2016, which will include a capital expenditures forecast for 2018 – 2020.
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.
5
At December 31, 2015, SCE’s rate base authorized in the 2015 GRC and recorded rate base for FERC jurisdictional assets
determined in accordance with SCE’s FERC formula rate are summarized as follows:
(in millions)
Authorized CPUC rate base from 2015 GRC1
Legacy meters
Additional rate base from Pole Loading and Deteriorated Poles Balancing Account2
Reduction in rate base from extension of bonus depreciation
Subtotal – CPUC rate base
FERC rate base2
Total rate base
Authorized Rate Base
$
$
$
17,552
147
329
(12)
18,016
5,307
23,323
1 Excludes rate base adjustment of $324 million. See "—Regulatory Proceedings—2015 General Rate Case" for further discussion.
2 Includes $13 million and $6 million reduction from extension of bonus depreciation for pole loading and FERC, respectively.
SCE’s forecasted rate base for 2016 and 2017 is as follows:
(in millions)
Based on total estimated capital expenditures1
Based on total estimated capital expenditures for 2016 – 2017 (using the range discussed above)
2016
$ 25,131
2017
$ 26,810
25,045
26,583
1 Refer to footnote 1 in previous table.
The forecasted rate base for 2016 and 2017 includes the net impact of extension of bonus depreciation, which reduces
average rate base by $298 million and $701 million, respectively.
Distribution Grid Development
Distribution Resources Plan
On July 1, 2015, SCE filed its DRP with the CPUC. The filing was made as part of a CPUC proceeding that was initiated to
support California's GHG reduction targets, modernize the electric distribution system to accommodate two-way flows of
energy associated with distributed energy resources, such as rooftop solar, and facilitate customer choice of new technologies
and services that reduce emissions and improve resilience. SCE’s DRP included an indicative forecast of capital investment
in distribution automation, substation automation, communications systems, technology platforms and applications, and grid
reinforcement. Subject to future CPUC guidance, SCE anticipates integrating authorization for revenue to support DRP
operation and maintenance and capital spending into future general rate cases, beginning with its 2018 – 2020 GRC. Capital
investments for 2016 – 2017 may be updated or revised based on developments and guidance received from the CPUC as a
part of the GRC, DRP rule making, technology availability, pace of distributed energy resource adoption, and other factors.
Charge Ready Program
In January 2016, the CPUC approved SCE's $22 million Charge Ready pilot program, which will allow SCE to install
infrastructure supporting approximately 1,500 electric vehicle charging stations, provide rebates to offset the cost of qualified
customer-owned charging stations, and implement a supporting market education effort. SCE will work with cities,
employers, apartment owners, charging equipment manufacturers and others to deploy qualified charging stations at locations
where cars may be parked for four hours or more. Under the pilot program, SCE will build, own and maintain the electric
infrastructure needed to serve the qualified charging stations at participating customer locations. Participating customers will
install, own, maintain, and operate the charging stations. The results of this pilot will help shape Phase 2 of the program,
which was proposed to cost an additional $333 million over four years. SCE will file an application to obtain CPUC approval
for Phase 2 after at least one year and 1,000 charging stations have been deployed.
6
Edison International Dividend Policy
In December 2015, Edison International declared a 15% increase to the annual dividend rate from $1.67 per share to
$1.92 per share. Edison International plans to increase its dividends to common shareholders at a higher than industry
average growth rate within its target payout ratio of 45% to 55% of SCE earnings in steps over time.
Regulatory Proceedings
2015 General Rate Case
On November 5, 2015, the CPUC approved a final decision in SCE's 2015 GRC. The decision authorized a revenue
requirement of $5.182 billion for 2015. The final decision authorized a ratemaking methodology that escalates capital
additions by 2% for both 2016 and 2017 and allows operation and maintenance expense to be escalated for 2016 and 2017
through the use of various escalation factors for labor, non-labor and medical expenses. The methodology adopted in the
decision results in a revenue requirement of $5.391 billion for 2016 and $5.663 billion for 2017. The final decision was
retroactive to January 1, 2015 and includes provisions related to tax repair deductions and for revenue adjustments discussed
below.
Tax Repair Deductions and Memorandum Account
Certain capital expenditures qualify as repairs for income tax purposes and are currently deductible. In each GRC, SCE
forecasts its federal and state taxes, including expected deductions for tax repairs ("tax repair deductions"). Income tax
benefits from tax repair deductions are flowed through to customers in establishing the authorized revenue requirement. The
effect of flow-through treatment of income taxes is to lower current customer rates but increase future customer rates for
recovery of deferred income taxes. Actual tax repair deductions exceeded forecasted tax repair deductions during
2012 – 2014. As part of the final decision in SCE's 2015 GRC, the CPUC adopted a rate base offset to reduce authorized
revenue in 2015 and future rate cases for income tax benefits related to 2012 – 2014 tax repair deductions which were in
excess of forecast and did not flow-through to customers. The final decision included $324 million of rate base offset to
SCE’s CPUC jurisdictional rate base and directed the amount to be amortized over 27 years on a straight line basis.
Previously, SCE recognized earnings and a regulatory asset of $382 million for deferred income taxes related to 2012 – 2014
tax repair deductions. As a result of the CPUC’s rate base offset, SCE wrote down this regulatory asset in full. The after-tax
charge was reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductions
the CPUC used to establish the rate base offset was based on SCE’s forecast of 2012 – 2014 tax repair deductions from the
Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the
actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In February 2016, SCE made an
advice filing with the CPUC to reduce SCE’s Base Revenue Requirement Balancing Account by $234 million during 2016
through 2020 subject to the outcome of audits that may be conducted by tax authorities. SCE does not expect to record a gain
or loss from this advice filing. The advice filing is subject to review and revision by the CPUC.
The 2015 GRC also established a tax accounting memorandum account (referred to as “TAMA”), which provides that
additional 2015 – 2017 tax benefits or costs associated with the following events be tracked: (1) tax accounting method
changes, (2) changes in tax laws and regulations impacting depreciation or tax repair deductions, (3) forecasted and actual
differences in tax repair deductions, and (4) the impact, if any, of a private letter ruling related to compliance with
normalization regulations of the IRS. As a result of this memorandum account together with the balancing account discussed
below, any differences between the forecasted tax repair deductions and actual tax repair deductions for 2015 – 2017 will be
adjusted annually through customer rates. Tax repair deductions during 2015 exceeded the amounts forecasted in the 2015
GRC. As a result, SCE recorded a regulatory liability of $212 million at December 31, 2015, for refunds to customers.
7
Pole Loading and Deteriorated Poles Balancing Account (“PLDPBA”)
The 2015 GRC established a balancing account for pole loading and deteriorated poles for 2015 – 2017. As a result of the
balancing account, authorized GRC revenue for operation and maintenance expenses for the pole loading program and capital
revenue requirement for both pole loading and deteriorated poles programs will be adjusted to recorded amounts subject to a
maximum amount for the years 2016 and 2017 in the aggregate. SCE is authorized to recover the revenue requirement
associated with up to 115% of the authorized spending (operation and maintenance expenses and capital expenditures) during
2016 and 2017 for the pole loading and deteriorated poles programs (there was no maximum amount applicable to 2015 or
prior years). SCE would not be entitled to the capital revenues requirement for capital expenditures in excess of the
maximum amounts.
Under PLDPBA, SCE earns a return on the rate base applicable to the pole loading and deteriorated pole programs. The rate
base for these programs averaged $625 million during 2015, which exceeded the baseline included in the 2015 GRC of
$296 million. As a result, SCE recorded additional income during 2015 of $26 million through the PLDPBA. This account
also reflects the impact from the difference between recorded and authorized operation and maintenance expenses and repair
and cost of removal tax deductions related to these programs. The regulatory liability recorded for refunds to customers under
PLDPBA was $36 million at December 31, 2015.
Cost of Capital
On November 25, 2015, the Executive Director of the CPUC granted the joint request submitted by SCE, PG&E, SDG&E,
and SoCalGas (collectively, the "Joint Investor-Owned Utilities") for a one-year extension of the due date for the Joint
Investor-Owned Utilities to file their next cost of capital applications. As extended, the Joint Investor-Owned Utilities must
file their next cost of capital applications by April 20, 2017 instead of April 20, 2016. SCE's authorized rate of return and
capital structure for CPUC-related activities will remain unchanged through December 31, 2017.
The Executive Director noted that, in order to effectuate the Joint Investor-Owned Utilities' agreement that their cost of
capital would not be adjusted for 2017, they would need to submit a petition to the CPUC requesting that it modify its
existing decision establishing the automatic adjustment mechanism. The Joint Investor-Owned Utilities submitted their
petition in December 2015. On February 12, 2016, the CPUC issued a proposed decision approving the Joint Investor-Owned
Utilities' petition. A final decision is expected by the end of February 2016.
Energy Efficiency Incentive Mechanism
In 2015, the CPUC awarded SCE incentives of $29 million for the 2011 – 2014 energy efficiency program years.
In September 2015, the CPUC granted TURN and ORA petitions and requests for rehearing of prior CPUC decisions related
to $74.5 million of incentive awards that SCE received for savings achieved by its 2006 – 2008 energy efficiency programs.
The TURN and ORA petitions allege that ex parte communications between PG&E and the former president of the CPUC,
which were disclosed in an October 2014 report filed by PG&E, taint the entire 2010 energy efficiency decision and that the
decision should be vacated. SCE disputes the assertion that SCE should be at risk to repay previously awarded incentives.
SCE cannot predict the outcome of these petitions.
FERC Formula Rates
In December 2015, SCE filed its 2016 annual update with the FERC with the rates effective from January 1, 2016 to
December 31, 2016. The update provided support for an increase in SCE's transmission revenue requirement of $182 million
or 20% over amounts currently authorized in rates. The increase is mainly due to the completion of several major
transmission projects in 2014 and refunds from prior periods.
Permanent Retirement of San Onofre and San Onofre OII Settlement
In November 2014, the CPUC approved the San Onofre OII Settlement Agreement that SCE had entered into with TURN,
ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth. The San Onofre OII Settlement
Agreement resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the
related outages and subsequent shutdown of San Onofre. The San Onofre OII Settlement Agreement does not affect
proceedings related to recoveries from third parties, but does describe how shareholders and customers will share any
recoveries. For further discussion of third-party recoveries, including claims against MHI, see "Notes to Consolidated
Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."
8
Challenges related to San Onofre CPUC Proceedings
A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the
CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and
December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case
appealed the dismissal to the Ninth Circuit in May 2015. Both the appeal and the application for rehearing remain pending.
Also in April 2015, the Alliance for Nuclear Responsibility ("A4NR") filed a petition to modify the CPUC's decision
approving the San Onofre OII Settlement Agreement based on SCE's alleged failures to disclose communications between
SCE and CPUC decision-makers pertaining to issues in the San Onofre OII. The petition seeks the reversal of the decision
approving the San Onofre OII Settlement Agreement and reopening of the OII proceeding. Subsequently, TURN and ORA
filed responses supporting A4NR's petition to reopen the San Onofre OII proceeding. In August 2015, ORA filed its own
petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement seeking to set aside the
settlement and reopen the San Onofre OII proceeding. SCE and SDG&E responded to this petition in September 2015. Both
petitions remain pending before the CPUC.
In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief
Executive Officer and Chief Financial Officer and was later amended to include SCE's former President as a defendant. The
lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte
contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than
initially reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International
common stock between March 21, 2014 and June 24, 2015.
Subsequently and also in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison
International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on
similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and
various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same
allegations was filed in August and was subsequently consolidated with the July 2015 federal derivative lawsuit.
In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison
International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the
federal derivative lawsuits discussed above.
In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief
Executive Officer and Treasurer by an Edison International employee, alleging claims under the Employee Retirement
Income Security Act ("ERISA"). The complaint purports to be filed on behalf of a class of Edison International employees
who were participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between
March 27, 2014 and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew
or should have known that investment in the Edison International Stock Fund was imprudent because the price of Edison
International common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte
communications with CPUC decision-makers related to the San Onofre OII.
SCE has produced documents and is otherwise cooperating with criminal investigations being conducted by the California
Attorney General and the U.S. Department of Justice. While the full scope of the investigations is not known to SCE, SCE's
document production and cooperation have included information relating to the settlement of the San Onofre OII and
interactions between SCE executives and CPUC decision-makers.
Edison International and SCE cannot predict the outcome of these proceedings.
Ex Parte Communications
In February 2015, SCE filed in the San Onofre OII proceeding a Late-Filed Notice of Ex Parte Communication regarding a
meeting in March 2013 between an SCE senior executive and the president of the CPUC, both of whom have since retired
from their respective positions. In August 2015, the OII Administrative Law Judge issued a ruling that nine additional
communications should have been reported in addition to a March 2013 communication that SCE had reported in February
2015. In December 2015, the CPUC issued a final decision that imposed a penalty of $16.74 million in connection with eight
communications that the decision finds should have been reported and two violations of a CPUC ethical rule.
9
RESULTS OF OPERATIONS
SCE
SCE's results of operations are derived mainly through two sources:
• Utility 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 utility earnings activities are
revenues or penalties related to incentive mechanisms, other operating revenue, and regulatory charges or disallowances.
• Utility 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. Utility 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.
Revenue Impact of 2015 GRC Decision
As indicated in the table below, revenue in the 2015 GRC decision is lower than the amount authorized in 2014 due to lower
operation and maintenance costs and income taxes. Accordingly, SCE will refund $451 million to customers beginning in
January 2016.
The following table summarizes the 2015 GRC decision compared to the amounts of revenue currently authorized:
(in millions)
Authorized revenue
Cost of service:
Operation and maintenance
Depreciation
Property and payroll taxes
Income taxes
Authorized return
2014
Authorized
Revenue
Exclude
San Onofre
Authorized
Revenue
2014
Authorized
Revenue
less San Onofre
2015 GRC
Final
Decision
Authorized
Revenue
(Decrease)
Increase
$
6,149
$
(516)
$
5,633
$
5,182
$
(451)
2,354
1,587
273
494
1,441
6,149
$
(352)
(91)
(13)
(13)
(47)
(516)
$
$
2,002
1,496
260
481
1,394
5,633
$
1,837
1,532
246
197
1,370
5,182
(165) 1
36
(14)
(284) 2
(24)
(451)
$
1 Authorized revenue for operation and maintenance costs decreased due to:
• $72 million reduction in cost-recovery activities, which does not impact earnings, primarily for pension, postretirement
benefits other than pensions (PBOP), medical and results sharing costs. These cost-recovery activities are recorded
through balancing accounts, which allow for recovery of these specific projects or program costs, subject to
reasonableness review.
• $93 million reduction for utility earning activities primarily from SCE's initiatives to improve operational efficiency
which has resulted in lower forecasted operation and maintenance costs than included in the 2014 authorized amounts.
2 Authorized revenue for income taxes decreased due to flow-through items for income tax benefits – primarily repair and
cost of removal deductions (see "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for a discussion on
flow-through regulatory accounting). Forecasted flow-through items increased in the 2015 GRC from the amounts
reflected in 2014 authorized revenue which is reflected as lower revenue requirement.
10
The following table is a summary of SCE's results of operations for the periods indicated.
(in millions)
2015
Utility
Cost-
Recovery
Activities
Utility
Earning
Activities
Total
Consolidated
Utility
Earning
Activities
2014
Utility
Cost-
Recovery
Activities
Total
Consolidated
Utility
Earning
Activities
2013
Utility
Cost-
Recovery
Activities
Total
Consolidated
Operating revenue
$ 6,305 $ 5,180 $
11,485 $ 6,831 $ 6,549 $
13,380 $ 6,602 $ 5,960 $
12,562
Purchased power and fuel
Operation and maintenance
Depreciation, decommissioning
and amortization
Property and other taxes
Impairment and other charges
Total operating expenses
Operating income
Interest expense
Other income and expenses
Income before income taxes
Income tax expense
Net income
Preferred and preference stock
dividend requirements
Net income available for
common stock
Core earnings1
Non-core earnings
Impairment and other charges
NEIL insurance recoveries
—
1,977
1,915
334
—
4,226
2,079
(525)
64
1,618
507
1,111
113
4,266
913
—
—
—
5,179
1
(1)
—
—
—
—
—
4,266
2,890
—
2,106
5,593
951
5,593
3,057
—
2,348
4,891
1,068
1,915
1,720
334
—
9,405
2,080
318
163
4,307
2,524
(526)
(528)
64
1,618
507
1,111
43
2,039
474
1,565
113
112
—
—
—
6,544
5
(5)
—
—
—
—
—
1,720
1,622
318
163
10,851
2,529
307
575
4,852
1,750
(533)
(519)
43
2,039
474
1,565
48
1,279
279
1,000
112
100
—
—
—
5,959
1
(1)
—
—
—
—
—
$
998 $
— $
998 $ 1,453 $
— $
1,453 $
900 $
— $
4,891
3,416
1,622
307
575
10,811
1,751
(520)
48
1,279
279
1,000
100
900
1,368
(382)
12
998
1,525
(72)
—
$
1,265
(365)
—
900
Total SCE GAAP earnings
$
$
1,453
$
1 See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results."
Utility Earning Activities
2015 vs 2014
Utility earning activities were primarily affected by the following:
• Lower operating revenue of $526 million is primarily due to:
• A decrease in authorized CPUC revenue of $379 million (excludes amounts classified as cost-recovery activities). The
decrease in revenue is primarily due to lower authorized revenue for operation and maintenance expenses and for
flow-through items for income tax benefits related to repair and cost of removal deductions.
• A decrease in revenue from approximately $300 million of tax benefits in excess of amounts authorized in the 2015
GRC and recognized through the TAMA and the pole loading balancing account (offset in income tax benefits
discussed below). In addition, SCE recorded $39 million ($26 million after-tax) of incremental return on the pole
loading rate base recorded through this balancing account.
• An increase in FERC-related revenue of $83 million primarily related to rate base growth and higher operating costs.
• An increase in San Onofre-related revenue of $40 million due to the implementation of the San Onofre OII Settlement
Agreement. Revenue for San Onofre for 2015 primarily related to recovery of amortization of the regulatory asset and
authorized return as provided by the San Onofre Settlement Agreement compared to revenue in 2014 related to
recovery of San Onofre's cost of service.
11
• Energy efficiency incentive awards were $29 million in 2015 compared to $22 million in 2014.
• SCE's portion of NEIL insurance and legal cost recoveries of approximately $20 million in 2015 (See "Notes to the
Consolidated Financial Statements—Note 11. Commitments and Contingencies—San Onofre Related Matters" for
further information on the agreement with NEIL).
• Higher revenue in 2014 from approval by the CPUC of a $30 million increase in the 2012-2014 authorized revenue
requirement related to deferred income taxes and from $15 million of generator settlements. See “Notes to the
Consolidated Financial Statements—Note 10. Regulatory Assets and Liabilities—Regulatory Balancing Accounts.”
• Lower operation and maintenance expense of $129 million primarily due to:
• Lower San Onofre-related expense of $93 million. During 2014, San Onofre-related expenses were recorded as
operation and maintenance expenses. During 2015, the CPUC authorized SCE reimbursement of 2014 costs from the
nuclear decommissioning trusts with such reimbursement subsequently refunded to customers. During 2015,
decommissioning expenses were reimbursed from the nuclear decommissioning trust and, therefore, did not result in
operation and maintenance expenses.
• A decrease of $77 million primarily related to transmission and distribution, legal, and customer service costs partially
offset by higher outside service costs in 2015.
• Higher severance costs related to workforce reduction efforts ($26 million in 2015 and $2 million in 2014).
•
In 2015, SCE incurred a penalty of $16.74 million related to ex parte communications (See "Notes to Consolidated
Financial Statements—Note 11. Commitments and Contingencies" for further information).
• Higher depreciation, decommissioning and amortization expense of $195 million primarily due to San Onofre-related
expense of $134 million in 2015 related to the amortization of the regulatory asset and a $61 million increase in
depreciation primarily related to transmission and distribution investments.
• Higher property and other taxes of $16 million primarily due to an increase in assessed property values in 2015.
•
Impairment and other charges of $163 million ($72 million after-tax) in 2014 related to the San Onofre OII Settlement
Agreement, as discussed below.
• Higher other income and expenses of $21 million primarily due to higher AFUDC equity income related to a higher rate
and higher construction work in progress balances in 2015 and a $15 million penalty recorded in 2014 resulting from the
San Bernardino and San Gabriel settlements. These increases were offset by $10 million of lower insurance benefits in
2015 and a $7 million sales tax refund related to San Onofre received in 2014. See "Notes to Consolidated Financial
Statements—Note 14. Interest and Other Income and Other Expenses" for further information.
• Higher income taxes of $33 million primarily due to the following:
• Write-down of $382 million in 2015 of regulatory assets previously recorded for recovery of deferred income taxes
from 2012 – 2014 incremental tax repair deductions. For further information, see "Management Overview—
Regulatory Proceedings—2015 General Rate Case."
• An increase in income tax benefits in 2015 primarily related to $263 million (after-tax) of repair deductions (offset in
operating revenue above) for TAMA and pole loading balancing account partially offset by lower tax benefits on other
property-related items in 2015.
• A change in liabilities related to uncertain tax positions related to repair deductions, which resulted in income tax
benefits of $100 million and $29 million during the second quarters of 2015 and 2014, respectively. See "—Income
Taxes" below for more information.
• Lower pre-tax income in 2015, as discussed above, partially offset by the impact of the San Onofre OII Settlement
Agreement.
12
2014 vs 2013
Utility earning activities were primarily affected by the following:
• Higher operating revenue of $229 million due to:
• An increase in CPUC-related revenue of $370 million primarily related to the increase in authorized revenue to
support rate base growth, including $30 million of additional revenue from revisions to its 2012 – 2014 GRC revenue
requirement related to deferred income taxes.
• An increase in FERC-related revenue of $130 million primarily related to rate base growth and higher operating costs,
including $19 million of additional revenue from a change in estimate under the FERC formula rate mechanism.
• Energy efficiency incentive awards were $22 million in 2014 compared to $14 million in 2013.
• Generator settlements of $15 million. See "Notes to Consolidated Financial Statements—Note 10. Regulatory Assets
and Liabilities—Regulatory Balancing Accounts."
• A decrease in San Onofre-related estimated revenue of $188 million, as discussed below.
• A decrease in Four Corners-related revenue of $105 million due to the sale of SCE's ownership interest in the Four
Corners Generating Station in December 2013 (primarily offset in operation and maintenance and depreciation
expense as indicated below).
• Lower operation and maintenance expense of $242 million primarily due to:
• A decrease in San Onofre-related expense of $179 million as discussed below and a decrease in Four Corners-related
expense of $60 million due to the sale in December 2013.
• A decrease in severance costs of $34 million (excluding San Onofre). In 2014 and 2013, SCE commenced multiple
efforts to reduce its workforce in order to reflect SCE's strategic direction to optimize its cost structure, moderate
customer rate increases and align its cost structure with its peers. Severance costs related to workforce reductions
(excluding severance related to the permanent retirement of San Onofre Units 2 and 3 recovered in the San Onofre OII
Settlement Agreement) were $4 million in 2014 and $38 million in 2013 (See "Notes to Consolidated Financial
Statements—Note 8. Compensation and Benefit Plans—Workforce Reductions"). SCE is continuing its efforts to
improve operational efficiency. These efforts may lead to additional severance or other charges which cannot be
estimated at this time.
•
A decrease of $30 million primarily related to lower customer service and outside service costs, as well as $20 million
of planned outage costs at Mountainview in 2013.
• An increase of $85 million of higher operating costs primarily related to transmission and distribution, information
technology, legal, safety and insurance costs.
• Higher depreciation, decommissioning and amortization expense of $98 million due to a $155 million increase in
depreciation mainly related to transmission and distribution investments, partially offset by a decrease in San Onofre-
related expense of $14 million discussed below and lower Four Corners-related expense of $45 million due to the sale in
December 2013.
•
Impairment charge of $163 million ($72 million after-tax) in 2014 related to the San Onofre OII Settlement Agreement, as
discussed below.
• Higher interest expense of $9 million primarily due to lower capitalized interest (AFUDC debt) and higher long-term debt
balances to support rate base growth.
• Lower other income and expenses of $5 million primarily due to lower AFUDC equity income related to lower AFUDC
rates and lower construction work in progress balances in 2014, lower interest income and higher other expenses, offset
by $7 million in sales tax refund related to San Onofre discussed below and lower penalties. In 2014 and 2013, SCE
incurred penalties of $15 million and $20 million, respectively, resulting from the San Bernardino and San Gabriel
settlements in 2014 and Malibu Fire Order Instituting Investigation settlement in 2013. See "Notes to Consolidated
Financial Statements—Note 14. Interest and Other Income and Other Expenses."
13
• Higher income taxes of $195 million primarily due to higher pre-tax income. See "—Income Taxes" below for more
information.
• Higher preferred and preference stock dividends of $12 million related to a new issuance in 2014.
On June 6, 2013, SCE decided to permanently retire San Onofre Units 2 and 3. During 2014, SCE entered into the San
Onofre OII Settlement Agreement to resolve CPUC regulatory issues associated with San Onofre. See "Management
Overview—Permanent Retirement of San Onofre and San Onofre OII Settlement" above for more information. The
following table summarizes the results of operations attributable to the San Onofre plant for the years ended December 31,
2014 and 2013, respectively, and is included in Utility Earnings above:
(in millions)
Revenue
Operating expenses
Operation and maintenance
Depreciation and amortization
Property and other taxes
Impairment and other charges
AFUDC
Total operating expenses
Loss before taxes
Years ended December 31,
2014
2013
$
166 1
$
354
93
44 2
16 3
163 4
—
316
(150)
$
272 5
58
23
575
(6)
922
(568)
$
1
Includes a 2014 revenue adjustment of $11 million related to a CPUC decision to refund Unit 1
decommissioning costs to the Nuclear Decommissioning Trusts.
2 Represents amortization of the San Onofre regulatory asset beginning October 1, 2014.
3
Includes property and sales tax refunds of $5 million and $7 million related to replacement steam
generators for the year ended December 31, 2014. The sales tax refund is included in "Interest and
other income" on the consolidated statements of income.
4 During the fourth quarter of 2014, SCE revised its estimated impact of the San Onofre OII
Settlement by $68 million ($24 million after-tax) consistent with advice filing for reimbursement of
recorded costs.
5
Includes severance costs of $63 million for the year ended December 31, 2013.
Utility Cost-Recovery Activities
2015 vs 2014
Utility cost-recovery activities were primarily affected by the following:
• Lower purchased power and fuel of $1.3 billion primarily driven by lower power and gas prices, the NEIL insurance
recoveries and the CAISO generation surcharge of $83 million in 2014 (as discussed below). These decreases were
partially offset by higher realized losses on economic hedging activities ($148 million in 2015 compared to $57 million in
2014). Fuel costs were $176 million in 2015 and $256 million in 2014.
During 2014, the CAISO issued invoices implementing a FERC order which revised FERC tariffs for costs associated
with scheduling coordinator activities. The impact of implementing the order and revised invoices resulted in a
transmission refund of $106 million reflected in operation and maintenance expense and a generation surcharge of
$83 million reflected in purchased power expense. These transactions did not impact earnings as the net refund was
provided to customers through a FERC balancing account mechanism.
• Lower operation and maintenance expense of $38 million primarily due to lower spending on various public purpose
programs, lower pension and benefit expenses and a decrease in transmission access charges, partially offset by the 2014
CAISO refund of $106 million as discussed above.
14
2014 vs 2013
Utility cost-recovery activities were primarily affected by the following:
• Higher purchased power and fuel expense of $702 million was primarily driven by an increased load related to warmer
weather and higher power and gas prices experienced in 2014 relative to 2013, partially offset by lower fuel expense in
2014 due to the sale of Four Corners in December 2013 and generator settlements refunded to customers (see "Notes to
Consolidated Financial Statements—Note 10. Regulatory Assets and Liabilities" for more information). In addition, in
2014, the CAISO issued invoices implementing a FERC order which revised FERC tariffs for costs associated with
scheduling coordinator activities. The impact of implementing the order and revised invoices resulted in a transmission
refund of $106 million reflected in operation and maintenance expense and a generation surcharge of $83 million reflected
in purchased power expense. These transactions did not impact earnings as the net refund was provided to customers
through a FERC balancing account mechanism. Fuel costs were $256 million in 2014 and $324 million in 2013.
• Lower operation and maintenance expense of $117 million primarily due to the CAISO refund of $106 million mentioned
above, a decrease in pension and postretirement benefit expenses and lower costs for the GHG cap-and-trade program
related to utility owned generation, partially offset by higher spending on various public purpose programs and higher
transmission access charges. See "Notes to Consolidated Financial Statements—Note 8. Compensation and Benefit Plans"
for more information.
Supplemental Operating Revenue Information
SCE's retail billed and unbilled revenue (excluding wholesale sales and balancing account over/undercollections) was
$12.2 billion for both 2015 and 2014 and $11.6 billion for 2013.
The 2015 revenue reflects:
• An increase of $160 million primarily due to the implementations of the 2014 ERRA rate increase in June 2014 and the
San Onofre-related rate adjustment in January 2015.
• A sales volume decrease of $169 million due to lower load requirements related to cooler weather experienced in 2015
compared to 2014.
The 2014 revenue reflects:
• An increase of $428 million primarily due to the implementation of the 2014 ERRA rate increase in June 2014 and the
increase in GRC authorized revenue, partially offset by the greenhouse gas auction revenue refunded to customers in April
and October 2014, and
• A sales volume increase of $226 million due to higher load requirements related to warmer weather experienced in 2014
compared to 2013.
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 provision increased by $33 million in 2015 compared to 2014. The effective tax rates were 31.3% and
23.2% for 2015 and 2014, respectively. The effective tax rate increase in 2015 was primarily due to the $382 million write-
down in 2015 of regulatory assets (discussed in "Management Overview—Regulatory Proceedings—2015 General Rate
Case") and income tax benefits in 2014 related to the San Onofre OII Settlement Agreement, partially offset by higher
income tax benefits related to tax repair deductions (as discussed above) and the change in liabilities related to uncertain tax
positions.
SCE's income tax provision increased by $195 million in 2014 compared to 2013. The effective tax rates were 23.2% and
21.8% for 2014 and 2013, respectively. The effective tax rate increase in 2014 was primarily due to higher state income taxes.
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. 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.
15
See "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for a reconciliation of the federal statutory rate of
35% to the effective income tax rates and "Management Overview—Permanent Retirement of San Onofre and San Onofre
OII Settlement" above for more information.
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 Continuing Operations
The following table summarizes the results of Edison International Parent and Other:
(in millions)
Edison Energy Group and subsidiaries
Edison Mission Group and subsidiaries
Corporate expenses and other1
Total Edison International Parent and Other
Years ended December 31,
2015
2014
2013
$
$
(6)
32
(39)
(13)
$
$
(5)
36
(57)
(26)
$
$
(3)
24
(42)
(21)
1 Includes interest expense (pre-tax) of $31 million, $25 million and $23 million in 2015, 2014, and 2013, respectively.
The loss from continuing operations of Edison International Parent and Other decreased $13 million in 2015 compared to
2014 primarily due to:
• A decrease in the loss of Corporate expenses and other primarily due to income tax benefits and lower corporate expenses
during 2015.
•
In December 2015, EMG's subsidiary, Edison Capital, completed the sale of its remaining affordable housing investment
portfolio which represents the exit of this business activity. Earnings from Edison Capital were $30 million and
$34 million for 2015 and 2014, respectively.
• An increase in losses of Edison Energy Group primarily due to higher operating expenses for 2015. The change was
partially offset by an increase in income allocated to subsidiaries of Edison Energy Group under the HLBV accounting
method that resulted in losses allocated to tax equity investors ($9 million and $2 million after-tax for 2015 and 2014,
respectively). For further information, see "Management Overview—Highlights of Operating Results."
The loss from continuing operations of Edison International Parent and other increased $5 million in 2014 compared to 2013
primarily due to:
• An increase in the loss of Corporate expenses and other primarily due to higher corporate expense.
• An increase in income from EMG and subsidiaries of $12 million primarily due to higher income from affordable housing
projects, including asset sales and income tax benefits. Earnings from Edison Capital were $34 million in 2014 and
$24 million in 2013.
Income from Discontinued Operations (Net of Tax)
Income from discontinued operations, net of tax, was $35 million, $185 million and $36 million for the years ended
December 31, 2015, 2014 and 2013, respectively. The 2015 income was primarily due to income tax benefits (from revised
estimates based on filing of the 2014 tax returns) and insurance recoveries. The 2014 income was related to the impact of
completing the transactions called for in the EME Settlement Agreement and income tax benefits from resolution of uncertain
tax positions and other impacts related to EME. The 2013 income was from income tax benefits of $36 million from revised
estimates of the tax impact of a tax deconsolidation of EME from Edison International as originally contemplated prior to the
EME Settlement.
16
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 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 Edison International, and the outcome of tax and regulatory matters.
SCE expects to fund its 2016 obligations, capital expenditures and dividends through operating cash flows, tax benefits and
capital market financings of debt and preferred equity, as needed. SCE also has availability under its credit facilities to fund
cash requirements.
Bonus Depreciation
The Protecting Americans from Tax Hikes ("PATH") Act of 2015 extended 50% bonus depreciation for qualifying property
retroactive to January 1, 2015 and through 2017 and provided for 40% bonus depreciation in 2018 and 30% in 2019. This
extension is expected to provide a cash flow benefit in 2015 for SCE as additional bonus depreciation deductions will reduce
tax liabilities.
Available Liquidity
At December 31, 2015, SCE had $2.58 billion available under its $2.75 billion credit facility. For further details see "Notes to
Consolidated Financial Statements—Note 5. Debt and Credit Agreements." SCE may finance balancing account
undercollections and working capital requirements to support operations and capital expenditures with commercial paper or
other borrowings, subject to availability in the capital markets.
Debt Covenant
The debt covenant in SCE's credit facility limits its debt to total capitalization ratio to less than or equal to 0.65 to 1. At
December 31, 2015, SCE's debt to total capitalization ratio was 0.44 to 1.
Capital Investment Plan – Major Transmission Projects
A summary of SCE's large transmission and substation projects during the next two years is presented below:
Project Name
Tehachapi 4-11
West of Devers
Mesa Substation
Project Lifecycle
Phase
In construction
In licensing
In licensing
Scheduled in Service Date
2016 – 2017
2021
2020
Direct
Expenditures1
(in millions)
$
2,479 $
1,075
608
2016 – 2017
Forecast
(in millions)
278
308
234
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 forecasted for 2016 – 2017.
Tehachapi
The Tehachapi Project consists of new and upgraded electric transmission lines and substations between eastern Kern County
and San Bernardino County and was undertaken to bring renewable resources in Kern County to energy consumers in the Los
Angeles basin and the California energy grid. The project consists of eleven segments. Segments 1-3 were placed in service
beginning in 2009 through 2013. Portions of segments 4-11 were placed in service in 2013 with the remaining portions
expected to be in service in 2016 and 2017.
The maximum cost estimate used by the CPUC to determine public need for segments 4-11 was established in 2009 at
$1.5 billion in 2009 dollars, which was lower than SCE’s requested cost estimate of $1.7 billion (cost estimates made in
Tehachapi regulatory filings are in constant dollars in the year of the filing and include direct expenditures and corporate
overhead costs). Subsequently, the estimated costs of the project increased due to a number of factors, including engineering
scope/design changes, licensing delays, added environmental mitigation and compliance costs, and added construction costs.
In addition, the CPUC ordered SCE to underground a 3.5-mile portion of the line that traverses Chino Hills; setting a
maximum cost estimate in 2013 of $224 million for the underground portion. The cost estimate that SCE had proposed in
2013 for the underground portion of the Tehachapi Project was $372 million. Separately, during 2013, the CPUC ordered
17
SCE to implement FAA-related scope changes, such as aviation marking and lighting. Including the underground portion of
the line, the CPUC has acknowledged a cost estimate to determine public need in 2013 of as much as $2.2 billion to
$2.3 billion. SCE has not yet filed a petition for modification with the CPUC for the current 2015 cost estimate of
approximately $2.75 billion. Opposition in other communities affected by the project could potentially cause further delays
and additional costs. Cost recovery for the project is subject to FERC review and approval.
West of Devers
The West of Devers Project upgrades SCE's existing West of Devers transmission line system by replacing a portion of the
existing 220 kV transmission lines and associated structures with higher-capacity transmission lines and structures. The West
of Devers Project is intended to facilitate the delivery of electricity produced by new electric generation resources that are
being developed or planned in eastern Riverside County. The CPUC has issued a final environmental impact report that
identifies an alternate project with a modified scope as an environmentally superior alternative, however a determination of
the scope of the project has not yet been finalized. If the CPUC ultimately adopts and approves the alternate project identified
in the environmental impact report, the schedule for commencing and completing the project will be delayed by as much as
two years. Morongo Transmission LLC holds an option to invest up to $400 million or half of the estimated cost of the
project at the commercial operation date in exchange for a 30-year lease right in the transfer capability of the project. If
Morongo Transmission LLC exercises its option, SCE’s rate base for this project would exclude the amount funded by
Morongo Transmission LLC.
Mesa Substation
The Mesa Substation Project consists of demolishing the existing 220 kV Mesa Substation and constructing a new 500 kV
substation. The Mesa 500 kV Substation project would 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. SCE has filed its permit to construct the
project with the CPUC and the project is included in the current 2016 – 2017 capital investment plan. SCE expects approval
on the permit to construct by the fourth quarter of 2016.
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. The decommissioning process is expected to
take many years. In June 2013, SCE began the initial activity phase of radiological decommissioning by filing with the NRC
a certification of permanent cessation of power operations at San Onofre. Notifications of permanent removal of fuel from the
reactor vessels were provided in June and July 2013 for Units 3 and 2, respectively. In August 2015, the NRC accepted SCE's
Post-Shutdown Decommissioning Activities Report ("PSDAR"), approved SCE's Irradiated Fuel Management Plan and
found SCE's Decommissioning Cost Estimate for San Onofre, Units 2 and 3 to be reasonable. SCE is currently permitted to
start major radiological decommissioning activities pursuant to NRC regulations, provided SCE obtains all necessary
environmental permits for decommissioning. During the second quarter of 2014, SCE updated its decommissioning cost
estimate based on a site specific assessment. The decommissioning cost estimate in 2014 dollars is $4.4 billion (SCE share is
$3.3 billion) and includes costs from June 7, 2013 through to the respective completion dates to decommission San Onofre
Units 2 and 3 estimated to be in 2052. The decommissioning cost estimate is 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 may remove spent fuel canisters from the San Onofre site,
as to which there can be no assurance. The cost estimate is subject to change and such changes may be material. For further
information, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Asset
Retirement Obligation."
SCE has nuclear decommissioning trust funds for San Onofre Units 2 and 3 of $2.9 billion as of December 31, 2015. If the
decommissioning cost estimate and assumptions regarding trust performance do not change, SCE believes that future
contributions to the trust funds will not be necessary.
The CPUC will conduct a reasonableness review for 2014 costs and years going forward. On July 23, 2015, the CPUC
approved SCE's request for access to the nuclear decommissioning trusts for reimbursement of 2013 and 2014 Units 2 and 3
decommissioning costs. Under the San Onofre OII Settlement Agreement, any recoveries from the nuclear decommissioning
trusts of 2013 and 2014 decommissioning costs funded through GRC revenue must be refunded to customers. In 2015, SCE
received $329 million of decommissioning funds and refunded this amount back to customers primarily through ERRA.
18
In 2015, SCE funded decommissioning costs (recorded as a reduction of SCE's asset retirement obligation) until the CPUC
approved SCE's request to access the trust funds for 2015 costs in November 2015. SCE's share of the decommissioning costs
recorded during 2015 were $216 million and are subject to reasonableness review by the CPUC.
SCE Dividends
SCE made $758 million and $378 million in dividend payments to its parent, Edison International, in 2015 and 2014,
respectively. The 2015 increase was due in part to a payment of $147 million in 2015 for outstanding dividends at the end of
2014. Future dividend amounts and timing of distributions are dependent upon several factors including the level of capital
expenditures, operating cash flows and earnings. See "Notes to Consolidated Financial Statements—Note 1. Summary of
Significant Accounting Policies—SCE Dividend Restrictions" for discussion of dividend restrictions.
Margin and Collateral Deposits
Certain derivative instruments, power procurement contracts and other contractual arrangements contain collateral
requirements. Future collateral requirements may differ from the requirements at December 31, 2015, due to the addition of
incremental power and energy procurement contracts with collateral requirements, if any, and the impact of changes in
wholesale power and natural gas prices on SCE's contractual obligations.
Some of the power procurement contracts contain provisions that require SCE to maintain an investment grade credit rating
from the major credit rating agencies. If SCE's credit rating were to fall below investment grade, SCE may be required to pay
the liability or post additional collateral.
The table below provides the amount of collateral posted by SCE to its counterparties as well as the potential collateral that
would be required as of December 31, 2015.
(in millions)
Collateral posted as of December 31, 20151
Incremental collateral requirements for power procurement contracts resulting from a
potential downgrade of SCE's credit rating to below investment grade
Incremental collateral requirements for power procurement contracts resulting from adverse
market price movement2
Posted and potential collateral requirements
$
$
173
31
30
234
1 Net collateral provided to counterparties and other brokers consisted of $15 million of cash which was offset against
net derivative liabilities on the consolidated balance sheets, $31 million of cash reflected in "Other current assets" on
the consolidated balance sheets and $127 million in letters of credit and surety bonds.
2
Incremental collateral requirements were based on potential changes in SCE's forward positions as of December 31,
2015 due to adverse market price movements over the remaining lives of the existing power procurement contracts
using a 95% confidence level.
Regulatory Balancing Accounts
SCE's cash flows are affected by regulatory balancing accounts over- or under-collections. Over- and under-collections
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 account. Under- or over-collections in these balancing accounts impact cash flows and can
change rapidly. Over- and under-collections accrue interest based on a three-month commercial paper rate published by the
Federal Reserve.
As of December 31, 2015, SCE had regulatory balancing account net overcollections of $2.0 billion, primarily consisting of
overcollections related to the base rate revenue account, energy resource recovery account, and public purpose-related and
energy efficiency program costs. Overcollections related to the base rate revenue account are expected to decrease as refunds
are provided to customers during 2016. Overcollections related to the energy resource recovery account are expected to
decrease as a result of the implementation of an ERRA rate change, effective January 1, 2016. Overcollections related to
public purpose-related programs are expected to decrease as costs are incurred to fund programs established by the CPUC.
See "Notes to Consolidated Financial Statements—Note 10. Regulatory Assets and Liabilities" for further information.
19
Edison International Parent and Other
Edison International Parent and Other's liquidity and its ability to pay operating expenses, make investments and pay
dividends to common shareholders are dependent on dividends from SCE and access to bank and capital markets. At
December 31, 2015, Edison International had $604 million available under its $1.25 billion credit facility. For further details,
see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements." Edison International may finance
working capital requirements to support operations and capital expenditures with commercial paper or other borrowings,
subject to availability in the capital markets. The debt covenant in Edison International's credit facility requires a consolidated
debt to total capitalization ratio of less than or equal to 0.65 to 1 as defined in the credit agreement. The Edison International's
consolidated debt to total capitalization ratio was 0.47 to 1 at December 31, 2015.
EME Settlement Agreement
In August 2014, Edison International entered into an amendment of the EME Settlement Agreement that finalized the
remaining matters related to the EME Settlement. Edison International made a payment of $204 million on September 30,
2015 and is scheduled to make a final payment of $214 million on September 30, 2016.
Edison International intends to make the remaining payment from realization of state tax benefits or issuance of commercial
paper or other borrowings. Edison International has $1.0 billion of net operating loss and tax credit carryforwards at
December 31, 2015 retained by EME which are available to offset future consolidated taxable income or tax liabilities. In
December 2015, the PATH Act of 2015 extended 50% bonus depreciation for qualifying property retroactive to January 1,
2015 and through 2017 and provided for 40% bonus depreciation in 2018 and 30% in 2019. As a result, realization of these
EME retained tax benefits has been deferred (currently forecasted through 2022). The timing of realization of these tax
benefits may be further delayed in the event of future extensions of bonus depreciation, and the value of the net operating loss
carryforwards could be permanently reduced if that tax reform decreased the current corporate tax rate.
Edison Energy Group Capital Expenditures
Forecasted capital expenditures for Edison Energy Group’s commercial solar activities are estimated to be $134 million in
2016. Edison Energy Group expects to finance these expenditures primarily with new project and tax equity financings and
an existing debt financing to support equity contributions similar to the existing financings arrangement used to fund 2015
capital expenditures. For further information, see "Notes to Consolidated Financial Statements—Note 9. Investments."
Historical Cash Flows
SCE
(in millions)
Net cash provided by operating activities
Net cash (used in) provided by financing activities
Net cash used by investing activities
Net (decrease) increase in cash and cash equivalents
2015
2014
2013
$
$
4,624
(812)
(3,824)
(12)
$
$
3,660
$
181
(3,857)
(16)
$
3,048
508
(3,547)
9
20
Net Cash Provided by Operating Activities
The following table summarizes major categories of net cash provided by operating activities as provided in more detail in
SCE's consolidated statements of cash flows for 2015, 2014 and 2013.
(in millions)
Net income
Non cash items1
Subtotal
Changes in cash flow resulting from working
capital2
Derivative assets and liabilities, net
Regulatory assets and liabilities, net
Other noncurrent assets and liabilities, net3
Net cash provided by operating activities
Years ended December 31,
Change in cash flows
2015
2014
2013
2015/2014
2014/2013
$
$
$
1,111 $
1,565 $
2,231
2,381
3,342 $
3,946 $
16
45
1,729
(508)
4,624 $
79
(40)
(358)
33
3,660 $
1,000
2,631
3,631
(182)
(30)
(322)
(49)
3,048
$
(604) $
315
(63)
85
2,087
(541)
964 $
$
261
(10)
(36)
82
612
1 Non cash items include depreciation, decommissioning and amortization, allowance for equity during construction, impairment and
other charges, deferred income taxes and investment tax credits and other.
2 Changes in working capital items include receivables, inventory, accounts payable, prepaid and accrued taxes, and other current assets
and liabilities.
3
Includes the decommissioning expenditures funded through the nuclear decommissioning trusts.
Net income and noncash items decreased in 2015 by $604 million from 2014 and increased in 2014 by $315 million from
2013. The decrease in 2015 was primarily due to the implementation of the 2015 GRC decision. The increase in 2014 was
primarily due to rate base growth. The factors that impacted these items are discussed under "Results of Operations—SCE—
Utility Earning Activities."
Changes in cash flows related to working capital items decreased in 2015 by $63 million from 2014 and increased in 2014 by
$261 million from 2013. In 2015, SCE had net tax payments of approximately $144 million, compared to net tax refunds of
$88 million in 2014 and net tax payments of $28 million in 2013. The refunds in 2014 were due to net operating loss
carrybacks to periods that SCE previously had taxable income. In 2015, 2014 and 2013, SCE had severance payments of
$39 million, $22 million and $151 million, respectively, related to the workforce reductions. In addition, the cash outflow in
2015 was due to the timing of receipts from customers and timing of disbursements.
Net cash provided by operating activities was also impacted by changes in regulatory assets and liabilities, including changes
in over (under) collections of balancing accounts. SCE has a number of balancing accounts under CPUC decisions, which
impact cash flows based on differences between timing of collection of amounts through rates and accrual expenditures.
While some balancing accounts are discrete, other balancing accounts are ongoing with changes generally collected in the
following year. The impact on cash flow from the following balancing accounts are:
• ERRA overcollections for fuel and purchased power for 2015 were $439 million due to lower than forecasted power and
gas prices experienced in 2015, refund related to the 2013 and 2014 nuclear decommissioning costs
(see "—Decommissioning of San Onofre" above) and the NEIL settlement proceeds from insurance claims arising out of
the failures of the San Onofre replacement steam generators. See "Notes to Consolidated Financial Statements—Note 11.
Commitments and Contingencies—Contingencies—San Onofre Related Matters" for further discussion. In January 2015,
SCE reclassified the regulatory liability for generator settlements to ERRA to refund customers as required by the CPUC.
ERRA undercollections for fuel and power procurement-related costs for 2014 and 2013 were $1.03 billion and
$1.0 billion, respectively, due to the amount and price of power and fuel being higher than forecasted. In December 2014,
SCE reclassified $540 million from regulatory liabilities to ERRA for collection of GRC revenue in excess of cost of
service related to San Onofre consistent with its advice filing in November 2014.
• The base rate revenue account ("BRRBA") tracks differences between amounts authorized by the CPUC in the GRC
proceedings and amounts billed to customers. SCE had BRRBA overcollections of $319 million, $5 million and
$247 million in 2015, 2014 and 2013, respectively. During 2015, the BBRBA account increased primarily due to revenue
previously collected from customers that is expected to be refunded as part of the 2015 GRC decision. The
21
overcollections were partially offset by lower electricity sales than forecasted in rates as a result of cooler weather
experienced in 2015.
During 2014, the BRRBA account decreased by $242 million due primarily to refunds to customers of approximately
$150 million, related to the sale of Four Corners in December 2013. During 2013, the BRRBA account impacted cash
flows by $752 million primarily due to the implementation of the 2012 GRC decision which resulted in a rate increase in
January 2013 to collect both the 2012 and 2013 rate increases. See "Results of Operations" for further discussion.
• The public purpose and energy efficiency programs track differences between amounts authorized by the CPUC and
amounts incurred to fund programs established by the CPUC. Overcollections decreased for these programs by
$191 million and $278 million in 2015 and 2014, respectively, primarily due to higher spending for these programs. The
decrease was partially offset by an increase in funding of the new system generation program for 2015 and 2014.
• The 2015 GRC Decision established a tax accounting memorandum account (referred to as "TAMA"). As a result of this
memorandum account, together with a balancing account for pole loading expenditures, any differences between the
forecasted tax repair deductions and actual tax repair deductions will be adjusted through customer rates. At December 31,
2015, SCE had a regulatory liability of $248 million related to these accounts (impact of TAMA is offset in non-cash
items above). See "Management Overview—Regulatory Proceedings—2015 General Rate Case—Tax Repair Deductions
and Memorandum Account" for further discussion.
Cash flows (used) provided by other noncurrent assets and liabilities were $(508) million, $33 million and $(49) million in
2015, 2014 and 2013, respectively. Major factors affecting cash flow related to non-current assets and liabilities were
activities related to SCE's nuclear decommissioning trusts (principally related to the payment of decommissioning costs).
Net Cash (Used in) Provided by Financing Activities
The following table summarizes cash provided by financing activities for 2015, 2014 and 2013. Issuances of debt and
preference stock are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Long-
Term Debt" and "—Note 12. Preferred and Preference Stock of Utility."
(in millions)
2015
2014
2013
Issuances of first and refunding mortgage bonds, net
$
1,287
$
498
$
Issuances of pollution control bonds, net and other
Long-term debt matured or repurchased
Short-term debt financing, net
Issuances of preference stock, net
Payments of common stock dividends to Edison International
Redemptions of preference stock
Payments of preferred and preference stock dividends
Other
Net cash (used in) provided by financing activities
Net Cash Used by Investing Activities
126
(761)
(619)
319
(758)
(325)
(116)
35
(812)
$
—
(607)
490
269
(378)
—
(111)
20
181
$
$
2,168
—
(1,016)
(1)
387
(486)
(400)
(101)
(43)
508
Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning
trusts. Capital expenditures were $4.2 billion for 2015, $3.9 billion for 2014 and $3.6 billion for 2013, primarily related to
transmission, distribution and generation investments. Net proceeds (purchases) of nuclear decommissioning trust
investments were $374 million, $(44) million and $(98) million for 2015, 2014 and 2013, respectively. See "Nuclear
Decommissioning Trusts" below for further discussion. The 2015 net proceeds from sale of nuclear decommissioning trust
investments was used to pay 2013, 2014 and a portion of 2015 decommissioning costs less net earnings during the period.
The 2014 net purchase of nuclear decommissioning trust investments was due to net earnings during the period. In December
2013, SCE completed the sale of its ownership interest in Units 4 and 5 of the Four Corners Generating Station which
resulted in $181 million of proceeds.
22
Nuclear Decommissioning Trusts
SCE's statement of cash flows includes activities of the Nuclear Decommissioning Trusts which are reflected in the following
line items:
(in millions)
Net cash (used in) provided by operating activities:
Nuclear decommissioning trusts
Net cash flow from investing activities:
Proceeds from sale of investments
Purchases of investments
Net cash impact
2015
2014
2013
$
$
(428) $
39 $
76
3,506
(3,132)
2,617
(2,661)
(54) $
(5) $
1,204
(1,302)
(22)
Net cash (used in) operating activities of the nuclear decommissioning trusts relate to interest and dividends less
administrative expenses, taxes and decommissioning costs. See "Notes to Consolidated Financial Statements—Note 9.
Investments" for further information. Such activities represent the source (use) of the funds for investing activities. The net
cash impact represents the contributions made by SCE to the nuclear decommissioning trusts. During 2015, SCE made a
contribution of $54 million to the non-qualified decommissioning trust related to tax benefits received and pursuant to a
CPUC decision related to decommissioning costs for San Onofre Unit 1.
In future periods, decommissioning costs of San Onofre will increase significantly. Such amounts will continue to be
reflected as a decrease in SCE net cash provided by operating activities and will be funded from sales of investments of the
nuclear decommissioning trusts once approved by the CPUC. Decommissioning costs incurred prior to CPUC approval will
be funded by SCE and are reflected as cash flow used by operating activities. See "Notes to Consolidated Financial
Statements—Note 9. Investments" for further information.
Edison International Parent and Other
The table below sets forth condensed historical cash flow from operations for Edison International Parent and Other.
(in millions)
Net cash used in operating activities
Net cash provided by financing activities
Net cash used in investing activities
Net increase (decrease) in cash and cash equivalents
Net Cash Used by Operating Activities
2015
2014
2013
$
$
(115)
224
(68)
41
$
$
(412)
464
(50)
2
$
$
(81)
73
(25)
(33)
Net cash used by operating activities decreased in 2015 by $297 million from 2014 and increased in 2014 by $331 million
from 2013 due to:
• $204 million and $225 million of cash payments made to the Reorganization Trust in September 2015 and April 2014
related to the EME Settlement Agreement, respectively, see "—Notes to Consolidated Financial Statements—Note 15.
Discontinued Operations—EME Chapter 11 Bankruptcy" for further information.
• $143 million receipt of intercompany tax-allocation payments in 2015 and a $189 million deposit made with the IRS in
2014 related to open tax years 2003 through 2006.
• $54 million cash outflow from operating activities in 2015, compared to $2 million cash inflow in 2014 and $81 million
cash outflow in 2013, due to the timing of payments and receipts relating to interest and operating costs.
23
Net Cash Provided by Financing Activities
Net cash provided by financing activities were as follows:
(in millions)
2015
2014
2013
Dividends paid to Edison International common shareholders
$
Dividends received from SCE
Payment for stock-based compensation
Receipt from stock option exercises
Debt financing, net1
Other
Net cash provided by financing activities
$
(544)
758
(119)
67
47
15
$
224
$
(463)
378
(106)
66
589
—
464
$
$
(440)
486
(25)
16
33
3
73
1
Includes $20 million debt financing for Edison Energy Group, see "Notes to Consolidated Financial Statements—Note 5. Debt and
Credit Agreements—Project Financings."
Net Cash Used by Investing Activities
Net cash used by investing activities during 2015 primarily relates to approximately $100 million in acquisitions of three
companies that support Edison Energy Group's commercial and industrial services growth strategy and $15 million related to
Edison Energy Group's capital expenditures for commercial solar installations. See "Notes to Consolidated Financial
Statements—Note 9. Investments" for further information.
Net cash used by investing activities during 2014 relate to Edison Energy Group's capital expenditures of $49 million for
commercial solar installations.
Contractual Obligations and Contingencies
Contractual Obligations
Edison International Parent and Other and SCE's contractual obligations as of December 31, 2015, for the years 2016 through
2020 and thereafter are estimated below.
(in millions)
SCE:
Long-term debt maturities and interest1
Power purchase agreements:2
Renewable energy contracts
Qualifying facility contracts
Other power purchase agreements
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
EME settlement payments
Total Edison International Parent and Other5
Total Edison International6,7
Total
Less than
1 year
1 to 3 years
3 to 5 years
More than
5 years
$
19,511
$
546
$
1,813
$
869
$
16,283
28,729
756
4,072
497
1,084
54,649
465
214
679
1,234
223
741
68
181
2,993
18
214
232
2,889
338
1,347
96
241
6,724
417
—
417
3,167
126
962
62
115
5,301
4
—
4
21,439
69
1,022
271
547
39,631
26
—
26
$
55,328
$
3,225
$
7,141
$
5,305
$
39,657
1 For additional details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements." Amount
includes interest payments totaling $8.86 billion and $34 million over applicable period of the debt for SCE and Edison
International Parent and Other, respectively.
24
2 Certain power purchase agreements entered into with independent power producers are treated as operating, capital or financing
leases. For further discussion, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies."
3 At December 31, 2015, SCE's minimum other operating lease payments were primarily related to vehicles, office space and
other equipment. For further discussion, see "Notes to Consolidated Financial Statements—Note 11. Commitments and
Contingencies."
4 For additional details, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies." At
December 31, 2015, other commitments were primarily related to maintaining reliability and expanding SCE's transmission and
distribution system, nuclear storage space and capacity reduction contracts.
5 At December 31, 2015, Edison International Parent and Other and SCE had estimated contributions to the pension and PBOP
plans. SCE estimated contributions are $127 million, $128 million in 2016 and 2017, respectively. Edison International Parent
and Other estimated contributions are $30 million and $23 million for the same respective periods. The estimated contributions
are not available beyond 2017. These amounts represent estimates that are based on assumptions that are subject to change. See
"Notes to Consolidated Financial Statements—Note 8. Compensation and Benefit Plans" for further information.
6 At December 31, 2015, Edison International and SCE had a total net liability recorded for uncertain tax positions of
$529 million and $353 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.
Contingencies
SCE has contingencies related to San Onofre Related Matters, Long Beach Service Interruptions, Nuclear Insurance, Wildfire
Insurance and Spent Nuclear Fuel which are discussed in "Notes to Consolidated Financial Statements—Note 11.
Commitments and Contingencies."
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.
As of December 31, 2015, SCE had identified 19 material sites for remediation and recorded an estimated minimum liability
of $131 million. SCE expects to recover 90% of its remediation costs at certain sites. See "Notes to Consolidated Financial
Statements—Note 11. Commitments and Contingencies" for further discussion.
Off-Balance Sheet Arrangements
SCE has variable interests in power purchase contracts with variable interest entities and a variable interest in unconsolidated
Trust I, Trust II, Trust III and Trust IV that issued $475 million (aggregate liquidation preference) of 5.625%, $400 million
(aggregate liquidation preference) of 5.10%, $275 million (aggregate liquidation preference) of 5.75% and $325 million
(aggregate liquidation preference) of 5.375%, trust securities, respectively, to the public, see "Notes to Consolidated Financial
Statements—Note 3. Variable Interest Entities."
Environmental Developments
For a discussion of environmental developments, see "Business—Environmental Regulation of Edison International and
Subsidiaries."
25
MARKET RISK EXPOSURES
Edison International 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 a 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, to fund business operations and to fund capital investments. The nature and
amount of Edison International 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 2017, see "Business—SCE—Overview of
Ratemaking Process—CPUC" for further discussion. The following table summarizes the increase or decrease to the fair
value of long-term debt including the current portion as of December 31, 2015, if the market interest rates were changed
while leaving all other assumptions the same:
(in millions)
Edison International
SCE
Commodity Price Risk
Carrying
Value
Fair Value
10% Increase
10% Decrease
$
$
11,259
10,616
$
12,252
11,592
$
11,754
11,095
12,789
12,128
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
arrangements, tolling 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 SCE's fair value 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 liability of
$1.2 billion and $927 million at December 31, 2015 and 2014, respectively. The following table summarizes the increase or
decrease to the fair values of the net liability of derivative instruments included in the consolidated balance sheets as of
December 31, 2015, 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%
December 31, 2015
$
147
(123)
(43)
49
26
Credit Risk
For information related to credit risks, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments."
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 setoff. 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 for both rated and non-rated counterparties based on published
credit ratings of counterparties 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. As of December 31, 2015, the amount of balance sheet exposure as described above broken down by the
credit ratings of SCE's counterparties, was as follows:
(in millions)
S&P Credit Rating1
A or higher
Not rated
Total
December 31, 2015
Exposure2
Collateral
Net Exposure
$
$
153
12
165
$
$
— $
(5)
(5)
$
153
7
160
1 SCE assigns a credit rating based on the lower of a counterparty's S&P or Moody's rating. For ease of
reference, the above table uses the S&P classifications to summarize risk, but reflects the lower of the two
credit ratings.
2 Exposure excludes amounts related to contracts classified as normal purchases and sales and non-derivative
contractual commitments that are not recorded on the consolidated balance sheets, except for any related net
accounts receivable.
CRITICAL ACCOUNTING ESTIMATES AND POLICIES
The accounting policies described below are considered critical to obtaining an understanding of Edison International 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 certain penalties or grant certain 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 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 are refundable to customers.
As discussed in "Management Overview—Regulatory Proceedings—2015 GRC," in November 2015, SCE received the 2015
GRC decision. As part of this decision, the CPUC adopted a rate base offset associated with forecasted tax repair deductions
during 2012 –2014. The 2015 rate base offset is $324 million and amortizes on a straight line basis over 27 years. As a result
of the rate base offset included in the final decision, SCE recorded an after tax charge of $382 million during the fourth
quarter of 2015 to write down the regulatory assets previously recorded for recovery of deferred income taxes related to
2012 – 2014 incremental tax repair deductions.
27
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.
Effect if Different Assumptions Used. Significant management judgment is required to evaluate the anticipated recovery of
regulatory assets, the recognition of incentives and revenue subject to refund, as well as the anticipated cost of regulatory
liabilities or penalties. If future recovery of costs ceases to be probable, all or part of the regulatory assets and liabilities
would have to be written off against current period earnings. At December 31, 2015, the consolidated balance sheets included
regulatory assets of $8.07 billion and regulatory liabilities of $6.8 billion. If different judgments were reached on recovery of
costs and timing of income recognition, SCE's earnings may vary from the amounts reported.
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 that can be used to reduce liabilities in future periods.
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 IRS, 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. Accounting for tax obligations requires management judgment. Edison International
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's management evaluates uncertain tax
positions at the end of each reporting period and makes adjustments when warranted based on changes in fact or law.
Effect if Different Assumptions Used. 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.
Nuclear Decommissioning – Asset Retirement Obligation
Key Assumptions and Approach Used. The liability to decommission SCE's nuclear power facilities is based on
decommissioning studies performed in 2010 for Palo Verde and San Onofre Unit 1 and a 2014 updated decommissioning cost
estimate for the retirement of San Onofre Units 2 and 3. See "Management Overview—Permanent Retirement of San Onofre
and San Onofre OII Settlement" for further discussion of the plans for decommissioning of San Onofre. SCE currently
estimates that it will spend approximately $7.2 billion through 2075 to decommission its nuclear facilities. Decommissioning
cost estimates are updated in each Nuclear Decommissioning Triennial Proceeding. The current ARO estimates for San
Onofre and Palo Verde are based on the assumptions from these decommissioning studies:
• Decommissioning Costs. The estimated costs for labor, dismantling and disposal costs, site remediation, energy and
miscellaneous costs.
• 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,
energy and low level radioactive waste burial costs. SCE's current estimate is based on SCE's decommissioning cost
28
methodology used for ratemaking purposes, escalated at rates ranging from 1.4% to 7.3% (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. Cost estimates for San Onofre are based on an assumption that decommissioning commenced in 2013.
For further information, see "Management Overview—Permanent Retirement of San Onofre and San Onofre OII
Settlement."
• Spent Fuel Dry Storage Costs. Cost estimates are based on an assumption that the DOE will begin to take spent fuel in
2024, and will remove the last spent fuel from the San Onofre and Palo Verde sites by 2055 and 2075, respectively. Costs
for spent fuel monitoring are included until 2055 and 2075, 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.
Effect if Different Assumptions Used. The ARO for decommissioning SCE's nuclear facilities was $2.7 billion as of
December 31, 2015, based on decommissioning studies performed in 2010 for Palo Verde, in 2011 for San Onofre Unit 1 and
in 2014 for San Onofre Unit 2 and 3. 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. SCE has issued a
request for proposal to engage a general contractor to undertake a significant scope of decommissioning activities for Units 2
and 3 at San Onofre and expects to make a selection during 2016. The ARO for decommissioning these units is expected to
be updated subsequent to the selection of a general contractor based, in part, on the results of the competitive selection
process.
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 100 basis points
Increase to ARO and
Regulatory Asset at
December 31, 2015
574
$
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 ("PBOP(s)")
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 its postretirement plans.
Key Assumptions of Approach Used. Pension and other postretirement 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, 2015, Edison International's and SCE's pension plans had a $4.4 billion and $3.9 billion benefit
obligation, respectively, and total 2015 expense for these plans was $118 million and $111 million, respectively. As of
December 31, 2015, the benefit obligation for both Edison International's and SCE's PBOP plans was $2.4 billion and
$2.3 billion, respectively, and total 2015 expense for Edison International's and SCE's plans was $24 million and $23 million,
respectively. 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.
29
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, 2015, this cumulative
difference amounted to a regulatory asset of $176 million, meaning that the accounting method has recognized more in
expense than the ratemaking method since implementation of authoritative guidance for employers' accounting for pensions
in 1987.
Edison International and SCE used the following critical assumptions to determine expense for pension and other
postretirement benefit for 2015:
(in millions)
Discount rate1
Expected long-term return on plan assets2
Assumed health care cost trend rates3
Pension
Plans
Postretirement
Benefits Other
than Pensions
3.85%
7.00%
*
4.16%
5.50%
7.75%
* Not applicable to pension plans.
1 The discount rate enables Edison International and SCE to state expected future cash flows at a present
value on the measurement date. Edison International and SCE select its discount rate by performing a yield
curve analysis. This analysis determines the equivalent discount rate on projected cash flows, matching the
timing and amount of expected benefit payments. The AON-Hewitt yield curve is considered in
determining the discount rate.
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 5.5% rate of return on plan assets above is determined on
an after-tax basis. Actual time-weighted, annualized returns on the pension plan assets were 1.1%, 8.4%
and 6.5% for the one-year, five-year and ten-year periods ended December 31, 2015, respectively. Actual
time-weighted, annualized returns on the PBOP plan assets were 0.3%, 8.3% and 5.7% 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 2021 and beyond.
As of December 31, 2015, Edison International and SCE had unrecognized pension costs of $771 million and $702 million,
and unrecognized PBOP costs of $178 million and $174 million, respectively. The unrecognized pension and PBOP costs
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, $675 million of
SCE's pension costs and $174 million of SCE's PBOP costs are recorded as regulatory assets, and will be amortized to
expense 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)
Change to projected benefit obligation for pension
Change to accumulated benefit obligation for PBOP
30
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%
$
(468) $
(321)
$
530
372
(410) $
(320)
459
371
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 $33 million and $31 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
$21 million.
The following table summarizes the increase or (decrease) to accumulated benefit obligation and annual aggregate service
and interest costs for PBOP if the health care cost trend rate was changed while leaving all other assumptions constant:
(in millions)
Edison International
SCE
Increase in
health care
cost trend
rate by 1%
Decrease in
health care
cost trend
rate by 1%
Increase in
health care
cost trend
rate by 1%
Decrease in
health care
cost trend
rate by 1%
Change to accumulated benefit obligation for PBOP
$
251
$
Change to annual aggregate service and interest costs
12
(206) $
(9)
250
$
12
(205)
(9)
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 a reserve 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 11. Commitments and Contingencies."
NEW ACCOUNTING GUIDANCE
New accounting guidance is discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant
Accounting Policies—New Accounting Guidance."
RISK FACTORS
RISKS RELATING TO EDISON INTERNATIONAL
Edison International's liquidity depends on SCE's ability to pay dividends and tax allocation payments to Edison
International, monetization of tax benefits retained by EME, and access to capital markets.
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 its ability to make upstream distributions. Prior to paying dividends to Edison International, SCE
has financial and regulatory obligations that must be satisfied, including, among others, debt service and preferred stock
dividends. In addition, 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 service obligations, shall receive first priority from the Boards of Directors of both
Edison International and SCE. SCE may also owe tax-allocation payments to Edison International under applicable tax-
allocation agreements. The EME Settlement Agreement requires Edison International to make fixed payments to a newly
formed trust under the control of EME's creditors (the "Reorganization Trust"). Edison International plans to use its credit
facilities or incur new debt to fund a portion of the Reorganization Trust payments due to delays in monetizing tax benefits
31
retained by EME as a result of the recent extension of bonus depreciation. Realization of such tax benefits may be further
delayed or permanently reduced by future tax legislation that extends bonus depreciation or reduces the current corporate tax
rate. Access to capital markets may be impacted by economic conditions that have an adverse effect on Edison International's
liquidity. 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 electricity industry. Its principal subsidiary, SCE, serves
customers only in southern and central California. Although Edison International is developing Competitive Businesses that
may diversify geographically beyond California, these businesses are not yet material. As a result, Edison International's
future performance may be affected by events and economic performance concentrated in California or by regional regulation
or legislation.
Edison International is developing Competitive Businesses that may not be successful.
Edison International is developing Competitive Businesses to capitalize on changes in the electricity industry. Edison
International intends to invest in companies to develop the capabilities of its Competitive Businesses but there can be no
assurance that Edison International will be successful in developing profitable Competitive Businesses.
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY
Regulatory Risks
SCE is subject to extensive regulation and the risk of adverse regulatory 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. The
construction, planning, and siting of SCE's power plants and transmission lines in California are also subject to regulation by
the CPUC.
SCE must periodically apply for licenses and permits from these various 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 penalties or disallowances on SCE, SCE's business could be materially
affected. The process of obtaining licenses and permits from regulatory authorities may be delayed or defeated by concerted
community opposition and such delay or defeat could have a material effect on SCE's business.
The CPUC is considering rulemaking to govern communications between the CPUC officials, staff and the regulated utilities.
Changes to the rules and processes around ex parte communications could result in delayed decisions, increased
investigations, enforcement actions and penalties. In addition, the CPUC or other parties may initiate investigations of past
communications between public utilities, including SCE, and CPUC officials and staff that could result in reopening
completed proceedings for reconsideration.
In addition, existing regulations may be revised or reinterpreted 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 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 from its customers in a timely manner its costs, 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 CPUC approves the recovery of
such costs. For example, the recovery of the Tehachapi transmission project costs are subject to FERC approval and the
32
public need for the project is reviewed by the CPUC. SCE has not yet filed a petition for modification with the CPUC to
reconfirm public need at an increased cost, estimated to be approximately $2.75 billion (2015 cost estimate). Including the
underground portion of the line, the CPUC has previously acknowledged a cost estimate to determine public need in 2013 of
as much as $2.2 billion to $2.3 billion. For more information, see "Liquidity—Capital Investment Plan – Major Transmission
Projects" in the MD&A. Changes in laws and regulations or changes in the political and regulatory environment also may
have an adverse effect on the SCE's ability to timely recover its costs and earn its authorized rate of return. In addition, SCE
may be required to incur costs to comply with new state laws or to implement new state policies before SCE is assured of
cost recovery.
SCE's capital investment plan, increasing procurement of renewable power and energy storage, increasing environmental
regulations, 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
material amounts of 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
—Regulatory Matters—2015 General Rate Case" and "—FERC Formula Rates" in the MD&A.
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. For instance, natural gas prices may increase due to the leak at the Southern California Gas Company
("SoCalGas") underground gas storage facility in Aliso Canyon, California. 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.
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, interest and preferred stock dividends, are dependent on numerous factors, including SCE's levels of indebtedness,
maintenance of acceptable credit ratings, its financial performance, liquidity and cash flow, and other market conditions.
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
The electricity industry is undergoing change, including increased competition, technological advancements, and political
and regulatory developments.
The electricity industry is undergoing change, including technological advancements such as energy storage, greater
deployment of distributed energy resources, such as customer-owned generation, and expansion of electric vehicles requiring
increased utility distribution infrastructure and modifications in customer electric load requirements that could alter the nature
of energy generation and delivery. In addition, there has been public discussion regarding the possibility of future changes in
the electric utility business model as a result of these developments. In October 2013, the CPUC held an open hearing to
receive views from various sources on whether the current California utility business model should be revised. It is possible
that revisions to the traditional utility business model could materially affect SCE's business model and its financial condition
and results of operations.
33
Demand for electricity from utilities has been leveling, while growth in customer-owned generation has increased. At the
same time, significant investment is needed to replace aging infrastructure and convert the electric distribution grid to support
two-way flows of electricity.
Customer-owned generation itself reduces the amount of electricity those customers purchase from utilities and has the effect
of increasing utility rates unless retail rates are designed to allocate the costs of the distribution grid across all customers that
benefit from their use. For example, customers in California that generate their own power do not currently 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. Such increases foster the public discussion regarding future
changes in the electric utility business model.
In addition, the FERC has adopted changes that have 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."
Operating Risks
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 order to mitigate this risk, SCE is engaged in a
significant and ongoing infrastructure investment program. This substantial investment program elevates the operational risks
and the need for superior execution in its 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, public opposition to infrastructure projects, delays, environmental mitigation costs,
difficulty in estimating costs or in recovering costs that are above original estimates, system limitations and degradation, and
interruptions in necessary supplies.
Weather-related incidents and other natural disasters could materially affect SCE's financial condition and results of
operations.
Weather-related incidents and other natural disasters, including storms, wildfires and earthquakes, can disrupt the generation
and transmission of electricity, and can seriously damage the infrastructure necessary to deliver power to SCE's customers.
These events can lead to lost revenues and increased expenses, including higher maintenance and repair costs. They can also
result in regulatory penalties and disallowances, particularly if SCE encounters difficulties in restoring power to its customers
on a timely basis. 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 dangerous and involve inherent risks of damage to private
property and injury to employees and the general public.
Electricity is dangerous for employees and the general public should they come in contact with electrical current or
equipment, including through downed power lines or if equipment malfunctions. Injuries and property damage caused by
such events can subject SCE to liability that, despite the existence of insurance coverage, can be significant. The CPUC has
increased its focus on public safety issues 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 $50,000 per violation per day, pursuant to the
CPUC's jurisdiction for violations of safety rules found in statutes, regulations, and the CPUC's General Orders. Such
penalties and liabilities could be significant and materially affect SCE's liquidity and results of operations.
34
There are inherent risks associated with owning and decommissioning nuclear power generating facilities and obtaining
cost reimbursement, including, among other things, potential harmful effects on the environment and human health and
the danger 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 expects to fund decommissioning costs with assets that are currently held in nuclear decommissioning trusts. The costs
of decommissioning Unit 2 and Unit 3 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.
Despite the fact that 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 $13.5 billion. SCE and other owners of the San Onofre and Palo Verde Nuclear
Generating Stations have purchased the maximum private primary insurance available of $375 million per site. If nuclear
incident liability claims were to exceed $375 million, the remaining amount would be made up from contributions of
approximately $13.1 billion made by all of the nuclear facility owners in the U.S., up to an aggregate total of $13.5 billion.
There is no assurance that the CPUC would allow SCE to recover the required contribution made in the case of one or more
nuclear incident claims that exceeded $375 million. If this public liability limit of $13.5 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 11. Commitments and Contingencies—Contingencies—Nuclear
Insurance."
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 from SCE's ordinary operations. In addition, the insurance that has been obtained for wildfire liabilities may not be
sufficient. Uninsured losses and increases in the cost of insurance may not be recoverable in customer rates. A loss which is
not fully insured or cannot be recovered in customer rates could materially affect Edison International's and SCE's financial
condition and results of operations. Furthermore, insurance for wildfire liabilities may not continue to be available at all or at
rates or on terms similar to those presently available to Edison International. For more information on wildfire insurance risk,
see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—Wildfire
Insurance."
Cybersecurity Risks
SCE's systems and network infrastructure may be vulnerable to physical and cyber attacks, intrusions or other
catastrophic events that could result in their failure or reduced functionality.
Regulators, such as the NERC, and U.S. Government Departments, including the Departments of Defense, Homeland
Security and Energy, have noted 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 becoming
increasingly sophisticated and dynamic. As SCE moves from an analog to a digital electric grid, new cyber security risks may
arise. An example of such new risks is the installation of "smart" meters in SCE's service territory. This technology may
represent a new route for attacks on SCE's information systems. SCE's operations require the continuous availability of
critical information technology systems and network infrastructure. SCE's systems have been, and will likely continue to be,
subjected to computer attacks of malicious codes, unauthorized access attempts, and other illicit activities, but to date, SCE
has not experienced a material cyber security breach. Although SCE actively monitors developments in this area and is
involved in various industry groups and government initiatives, no security measures can completely shield such systems and
infrastructure from vulnerabilities to cyber attacks, intrusions or other catastrophic events that could result in their failure or
reduced functionality. If SCE's information 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, financial loss to SCE or to its customers, loss of confidence in SCE's security
measures, customer dissatisfaction, and significant litigation 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.
35
Environmental Risks
SCE is subject to extensive environmental regulations that may involve significant and increasing costs and materially
affect SCE.
SCE is subject to extensive and frequently changing environmental regulations and permitting requirements that involve
significant and increasing costs and substantial uncertainty. SCE devotes significant resources to environmental monitoring,
pollution control equipment, mitigation projects, and emission allowances to comply with existing and anticipated
environmental regulatory requirements. However, the current trend is toward more stringent standards, stricter regulation, and
more expansive application of environmental regulations. The adoption of laws and regulations to implement greenhouse gas
controls could materially affect operations of power plants, which could in turn impact electricity markets and SCE's
purchased power costs. SCE may also be exposed to risks arising from past, current or future contamination at its former or
existing facilities or with respect to offsite waste disposal sites that have been used in its operations. Other environmental
laws, particularly with respect to air emissions, disposal of ash, wastewater discharge and cooling water systems, are also
generally becoming more stringent. The operation of SCE facilities under such laws and regulations may require substantial
capital expenditures for environmental controls or cessation of operations. Current and future state laws and regulations in
California also could increase the required amount of energy that must be procured from renewable resources. Environmental
regulations and permitting requirements also affect the cost and timing of transmission and distribution projects. See
"Business—Environmental Regulation of Edison International and Subsidiaries" for further discussion of environmental
regulations under which SCE operates.
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
36
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and
Shareholders of Edison International
In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income,
comprehensive income, changes in equity and cash flows present fairly, in all material respects, the financial position of
Edison International and its subsidiaries at December 31, 2015 and 2014, and the results of their operations and their cash
flows for each of the three years in the period ended December 31, 2015 in conformity with accounting principles generally
accepted in the United States of America. In addition, in our opinion, the financial statement schedules appearing under Item
15 (a) (2) present fairly, in all material respects, the information set forth therein when read in conjunction with the related
consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal
control over financial reporting as of December 31, 2015, based on criteria established in Internal Control – Integrated
Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The
Company's management is responsible for these financial statements and financial statement schedules, 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 these financial statements, on the financial statement schedules, and on the
Company's internal control over financial reporting based on our integrated audits. We conducted our audits in accordance
with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan
and perform the audits to obtain reasonable assurance about whether the financial statements are free of material
misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our
audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the
financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating
the overall financial statement presentation. 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.
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally
accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures
that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and
dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to
permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and
expenditures of the company are being made only in accordance with authorizations of management and directors of the
company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or
disposition of the company's assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also,
projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate
because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ PricewaterhouseCoopers LLP
Los Angeles, California
February 23, 2016
37
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and
Shareholders of Southern California Edison Company
In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income,
comprehensive income, changes in equity and cash flows present fairly, in all material respects, the financial position of
Southern California Edison Company and its subsidiaries at December 31, 2015 and 2014, and the results of their operations
and their cash flows for each of the three years in the period ended December 31, 2015 in conformity with accounting
principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule
appearing under Item 15 (a)(2) presents fairly, in all material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements. These financial statements and financial statement schedule
are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements
and financial statement schedule based on our audits. We conducted our audits of these statements in accordance with the
standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An
audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements,
assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis for our opinion.
/s/ PricewaterhouseCoopers LLP
Los Angeles, California
February 23, 2016
38
(This page has been left blank intentionally.)
39
Consolidated Statements of Income
Edison International
(in millions, except per-share amounts)
Total operating revenue
Purchased power and fuel
Operation and maintenance
Depreciation, decommissioning and amortization
Property and other taxes
Impairment and other charges
Total operating expenses
Operating income
Interest and other income
Interest expense
Other expenses
Income from continuing operations before income taxes
Income tax expense
Income from continuing operations
Income from discontinued operations, net of tax
Net income
Preferred and preference stock dividend requirements of utility
Other noncontrolling interests
Net income attributable to Edison International common shareholders
Amounts attributable to Edison International common shareholders:
Income from continuing operations, net of tax
Income from discontinued operations, net of tax
Net income attributable to Edison International common shareholders
Basic earnings per common share attributable to Edison International
common shareholders:
Weighted-average shares of common stock outstanding
Continuing operations
Discontinued operations
Total
Diluted earnings 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
Dividends declared per common share
Years ended December 31,
2015
2014
2013
$
11,524
$
13,413
$
12,581
4,266
2,990
1,919
336
5
9,516
2,008
174
(555)
(59)
1,568
486
1,082
35
1,117
113
(16)
1,020
985
35
1,020
326
3.02
0.11
3.13
329
2.99
0.11
3.10
1.7325
5,593
3,149
1,720
322
157
4,891
3,473
1,622
309
571
10,941
10,866
2,472
147
(560)
(80)
1,979
443
1,536
185
1,721
112
(3)
1,612
1,427
185
1,612
326
4.38
0.57
4.95
329
4.33
0.56
4.89
1.4825
1,715
124
(544)
(74)
1,221
242
979
36
1,015
100
—
915
879
36
915
326
2.70
0.11
2.81
329
2.67
0.11
2.78
1.3675
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
The accompanying notes are an integral part of these consolidated financial statements.
40
Consolidated Statements of Comprehensive Income
Edison International
(in millions)
Net income
Other comprehensive income (loss), net of tax:
Pension and postretirement benefits other than pensions:
Net gain (loss) arising during the period plus amortization included in
net income (loss)
Prior service cost arising during the period plus amortization included
in net loss
Other
Other comprehensive income (loss), net of tax
Comprehensive income
Less: Comprehensive income attributable to noncontrolling interests
Comprehensive income attributable to Edison International
Years ended December 31,
2015
2014
2013
$
1,117
$
1,721
$
1,015
1
1
—
2
1,119
97
(47)
—
2
(45)
1,676
109
$
1,022
$
1,567
$
72
—
2
74
1,089
100
989
The accompanying notes are an integral part of these consolidated financial statements.
41
Consolidated Balance Sheets
(in millions)
ASSETS
Cash and cash equivalents
Receivables, less allowances of $62 and $68 for uncollectible accounts at respective dates
Accrued unbilled revenue
Inventory
Derivative assets
Regulatory assets
Other current assets
Total current assets
Nuclear decommissioning trusts
Other investments
Total investments
Utility property, plant and equipment, less accumulated depreciation and amortization of
$8,548 and $8,132 at respective dates
Nonutility property, plant and equipment, less accumulated depreciation of $85 and $76 at
respective dates
Total property, plant and equipment
Derivative assets
Regulatory assets
Other long-term assets
Total long-term assets
$
Edison International
December 31,
2015
2014
161
771
565
267
79
560
251
2,654
4,331
203
4,534
$
132
790
632
281
102
1,254
376
3,567
4,799
207
5,006
34,945
32,859
140
35,085
84
7,512
441
8,037
122
32,981
219
7,612
349
8,180
Total assets
$
50,310
$
49,734
The accompanying notes are an integral part of these consolidated financial statements.
42
Consolidated Balance Sheets
(in millions, except share amounts)
LIABILITIES AND EQUITY
Short-term debt
Current portion of long-term debt
Accounts payable
Accrued taxes
Customer deposits
Derivative liabilities
Regulatory liabilities
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes and credits
Derivative liabilities
Pensions and benefits
Asset retirement obligations
Regulatory liabilities
Other deferred credits and other long-term liabilities
Total deferred credits and other liabilities
Total liabilities
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest
Common stock, no par value (800,000,000 shares authorized; 325,811,206 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 utility
Total equity
Edison International
December 31,
2015
2014
$
695
295
1,310
72
242
218
1,128
967
4,927
10,964
7,480
1,100
1,759
2,764
5,676
2,246
21,025
36,916
$
1,291
504
1,580
81
221
196
401
1,205
5,479
10,234
6,861
1,052
2,155
2,821
5,889
2,255
21,033
36,746
6
6
2,484
(56)
8,940
11,368
2,020
13,388
2,445
(58)
8,573
10,960
2,022
12,982
Total liabilities and equity
$
50,310
$
49,734
The accompanying notes are an integral part of these consolidated financial statements.
43
Consolidated Statements of Cash Flows
Edison International
(in millions)
Cash flows from operating activities:
Net income
Less: Income from discontinued operations
Income from continuing operations
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization
Allowance for equity during construction
Impairment and other charges
Deferred income taxes and investment tax credits
Other
Nuclear decommissioning trusts
EME settlement insurance proceeds and settlement payments
Changes in operating assets and liabilities:
Receivables
Inventory
Accounts payable
Prepaid and accrued taxes
Other current assets and liabilities
Derivative assets and liabilities, net
Regulatory assets and liabilities, net
Other noncurrent assets and liabilities
Net cash provided by operating activities
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs of $17,
$6, and $19 at respective periods
Long-term debt matured or repurchased
Preference stock issued, net
Preference stock redeemed
Short-term debt financing, net
Cash contribution from redeemable noncontrolling interest
Dividends to noncontrolling interests
Dividends paid
Other
Net cash (used in) 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 assets
Other
Net cash used in investing activities
Net increase (decrease) in cash and cash equivalents
Cash and cash equivalents at beginning of year
Cash and cash equivalents at end of year
Years ended December 31,
2014
2013
2015
$
$
1,117
35
1,082
2,005
(87)
5
449
(28)
(428)
(176)
49
14
8
(28)
(24)
45
1,729
(106)
4,509
1,420
(762)
319
(325)
(572)
17
(116)
(544)
(25)
(588)
$
1,721
185
1,536
1,815
(65)
157
522
20
39
(225)
64
(25)
14
(100)
(103)
(40)
(358)
(3)
3,248
494
(607)
269
—
1,079
9
(111)
(463)
(25)
645
(4,225)
3,506
(3,132)
47
(88)
(3,892)
29
132
161
$
(3,906)
2,617
(2,661)
6
37
(3,907)
(14)
146
132
$
$
1,015
36
979
1,696
(72)
571
345
18
76
—
(56)
80
45
(92)
(155)
(30)
(322)
(116)
2,967
2,168
(1,017)
387
(400)
32
—
(101)
(440)
(48)
581
(3,599)
1,204
(1,302)
181
(56)
(3,572)
(24)
170
146
The accompanying notes are an integral part of these consolidated financial statements.
44
Consolidated Statements of Changes in Equity
Edison International
(in millions)
Equity Attributable to Common Shareholders
Accumulated
Other
Comprehensive
Loss
Common
Stock
Retained
Earnings
Subtotal
Noncontrolling
Interests
Preferred
and
Preference
Stock
Total
Equity
Balance at December 31, 2012
$ 2,373
$
(87) $ 7,146
$ 9,432
$
1,759
$ 11,191
Net income
Other comprehensive income
Common stock dividends declared ($1.3675 per
share)
Dividends and distributions to noncontrolling
interests and other
Stock-based compensation and other
Noncash stock-based compensation and other
Issuance of preference stock
Redemption of preference stock
Balance at December 31, 2013
Net income
Other comprehensive loss
Common stock dividends declared ($1.4285 per
share)
Dividends and distributions to noncontrolling
interests and other
Stock-based compensation and other
Noncash stock-based compensation and other
Issuance of preference stock
Balance at December 31, 2014
Net income
Other comprehensive income
Common stock dividends declared ($1.7325 per
share)
Dividends and distributions to noncontrolling
interests and other
Stock-based compensation and other
Noncash stock-based compensation and other
Issuance of preference stock
Redemption of preference stock
Balance at December 31, 2015
—
—
—
—
5
25
—
—
$ 2,403
$
—
—
—
—
15
27
—
—
74
—
—
—
—
915
—
915
74
(446)
(446)
—
(53)
(6)
—
—
—
(13) $ 7,548
(8)
—
(48)
19
—
(8)
100
—
—
(100)
—
(1)
387
(392)
1,015
74
(446)
(100)
(48)
18
387
(400)
$ 9,938
$
1,753
$ 11,691
—
(45)
1,612
1,612
—
(45)
—
—
—
—
—
(483)
(483)
—
(104)
—
—
—
(89)
27
—
112
—
—
(112)
—
—
269
1,724
(45)
(483)
(112)
(89)
27
269
$ 2,445
$
(58) $ 8,573
$ 10,960
$
2,022
$ 12,982
—
—
—
—
15
24
—
—
—
2
—
—
—
—
—
—
1,020
1,020
—
2
(564)
(564)
—
(85)
—
—
(4)
—
(70)
24
—
(4)
113
—
—
(113)
—
—
319
(321)
1,133
2
(564)
(113)
(70)
24
319
(325)
$ 2,484
$
(56) $ 8,940
$ 11,368
$
2,020
$ 13,388
The accompanying notes are an integral part of these consolidated financial statements.
45
(This page has been left blank intentionally.)
46
Consolidated Statements of Income
Southern California Edison Company
(in millions)
Operating revenue
Purchased power and fuel
Operation and maintenance
Depreciation, decommissioning and amortization
Property and other taxes
Impairment and other charges
Total operating expenses
Operating income
Interest and other income
Interest expense
Other expenses
Income before income taxes
Income tax expense
Net income
Years ended December 31,
2015
2014
2013
$
11,485
$ 13,380
$
12,562
4,266
2,890
1,915
334
—
9,405
2,080
123
(526)
(59)
1,618
507
1,111
113
998
5,593
3,057
1,720
318
163
4,891
3,416
1,622
307
575
10,851
10,811
2,529
122
(533)
(79)
2,039
474
1,565
112
$
1,453
$
1,751
122
(520)
(74)
1,279
279
1,000
100
900
Less: Preferred and preference stock dividend requirements
Net income available for common stock
$
Consolidated Statements of Comprehensive Income
(in millions)
Net income
Other comprehensive income (loss), net of tax:
Pension and postretirement benefits other than pensions:
Net gain (loss) arising during period plus amortization included in net
income
Prior service cost arising during the period plus amortization included in
net income
Other
Other comprehensive income (loss), net of tax
Comprehensive income
Years ended December 31,
2014
2013
2015
$
1,111
$
1,565
$
1,000
5
1
—
6
1,117
(19)
—
2
(17)
1,548
$
16
—
2
18
1,018
$
$
The accompanying notes are an integral part of these consolidated financial statements.
47
Consolidated Balance Sheets
Southern California Edison Company
(in millions)
ASSETS
Cash and cash equivalents
Receivables, less allowances of $62 and $68 for uncollectible accounts at respective dates
Accrued unbilled revenue
Inventory
Derivative assets
Regulatory assets
Other current assets
Total current assets
Nuclear decommissioning trusts
Other investments
Total investments
Utility property, plant and equipment, less accumulated depreciation of $8,548 and $8,132 at
respective dates
Nonutility property, plant and equipment, less accumulated depreciation of $81 and $75 at
respective dates
Total property, plant and equipment
Derivative assets
Regulatory assets
Other long-term assets
Total long-term assets
$
December 31,
2015
2014
26
724
564
256
79
560
234
2,443
4,331
168
4,499
$
38
749
632
275
102
1,254
390
3,440
4,799
158
4,957
34,945
32,859
73
35,018
84
7,512
316
7,912
69
32,928
219
7,612
300
8,131
Total assets
$
49,872
$
49,456
The accompanying notes are an integral part of these consolidated financial statements.
48
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
Accrued taxes
Customer deposits
Derivative liabilities
Regulatory liabilities
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes and credits
Derivative liabilities
Pensions and benefits
Asset retirement obligations
Regulatory liabilities
Other deferred credits and other long-term liabilities
Total deferred credits and other liabilities
Total liabilities
Commitments and contingencies (Note 11)
Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and
outstanding at each date)
Additional paid-in capital
Accumulated other comprehensive loss
Retained earnings
Total common shareholder's equity
Preferred and preference stock
Total equity
Total liabilities and equity
December 31,
2015
2014
$
$
49
79
1,299
46
242
218
1,128
760
3,821
10,537
9,073
1,100
1,284
2,762
5,676
1,947
21,842
36,200
2,168
652
(22)
8,804
11,602
2,070
13,672
49,872
$
$
667
300
1,556
87
221
196
401
1,183
4,611
9,624
8,497
1,052
1,672
2,819
5,889
2,010
21,939
36,174
2,168
618
(28)
8,454
11,212
2,070
13,282
49,456
The accompanying notes are an integral part of these consolidated financial statements.
49
Consolidated Statements of Cash Flows
(in millions)
Cash flows from operating activities:
Net income
Adjustments to reconcile to net cash provided by operating activities:
Southern California Edison Company
Years ended December 31,
2014
2013
2015
$
1,111
$
1,565
$
1,000
Depreciation, decommissioning and amortization
Allowance for equity during construction
Impairment and other charges
Deferred income taxes and investment tax credits
Other
Nuclear decommissioning trusts
Changes in operating assets and liabilities:
Receivables
Inventory
Accounts payable
Prepaid and accrued taxes
Other current assets and liabilities
Derivative assets and liabilities, net
Regulatory assets and liabilities, net
Other noncurrent assets and liabilities
Net cash provided by operating activities
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs of
$17, $2 and $19, at respective dates
Long-term debt matured or repurchased
Preferred stock issued, net
Preference stock redeemed
Short-term debt financing, net
Dividends paid
Other
Net cash (used in) 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 assets
Other
Net cash used in investing activities
Net (decrease) increase in cash and cash equivalents
Cash and cash equivalents, beginning of year
Cash and cash equivalents, end of year
1,996
(87)
—
308
14
(428)
25
19
30
(16)
(42)
45
1,729
(80)
4,624
1,413
(761)
319
(325)
(619)
(874)
35
(812)
(4,210)
3,506
(3,132)
—
12
(3,824)
(12)
38
1,810
(65)
163
462
11
39
64
(19)
12
129
(107)
(40)
(358)
(6)
3,660
498
(607)
269
—
490
(489)
20
181
(3,857)
2,617
(2,661)
4
40
(3,857)
(16)
54
$
26
$
38
$
1,694
(72)
575
420
14
76
(57)
80
59
(93)
(171)
(30)
(322)
(125)
3,048
2,168
(1,016)
387
(400)
(1)
(587)
(43)
508
(3,598)
1,204
(1,302)
181
(32)
(3,547)
9
45
54
The accompanying notes are an integral part of these consolidated financial statements.
50
Consolidated Statements of Changes in Equity
Southern California Edison Company
(in millions)
Equity Attributable to Edison International
Common
Stock
Additional
Paid-in
Capital
Accumulated
Other
Comprehensive
Loss
Preferred
and
Preference
Stock
Total
Equity
Retained
Earnings
Balance at December 31, 2012
$
2,168
$
581
$
(29) $
7,228
$
1,795
$11,743
Net income
Other comprehensive income
Dividends declared on common stock
Dividends declared on preferred and preference stock
Stock-based compensation
Noncash stock-based compensation
Issuance of preference stock
Redemption of preference stock
Balance at December 31, 2013
Net income
Other comprehensive loss
Dividends declared on common stock
Dividends declared on preferred and preference stock
Stock-based compensation
Noncash stock-based compensation
Issuance of preference stock
—
—
—
—
—
—
—
—
—
—
—
—
1
15
(13)
8
—
18
—
—
—
—
—
—
1,000
—
(486)
(100)
(44)
4
—
(8)
—
—
—
—
—
—
400
(400)
1,000
18
(486)
(100)
(43)
19
387
(400)
$
2,168
$
592
$
(11) $
7,594
$
1,795
$12,138
—
—
—
—
—
—
—
—
—
—
—
20
12
(6)
—
(17)
—
—
—
—
—
1,565
—
(525)
(112)
(64)
(4)
—
—
—
—
—
—
—
275
1,565
(17)
(525)
(112)
(44)
8
269
Balance at December 31, 2014
$
2,168
$
618
$
(28) $
8,454
$
2,070
$13,282
Net income
Other comprehensive income
Dividends declared on common stock
Dividends declared on preferred and preference stock
Stock-based compensation
Noncash stock-based compensation
Issuance of preference stock
Redemption of preference stock
Balance at December 31, 2015
—
—
—
—
—
—
—
—
—
—
—
—
23
13
(6)
4
—
6
—
—
—
—
—
—
1,111
—
(611)
(113)
(33)
—
—
(4)
—
—
—
—
—
—
325
(325)
1,111
6
(611)
(113)
(10)
13
319
(325)
$
2,168
$
652
$
(22) $
8,804
$
2,070
$13,672
The accompanying notes are an integral part of these consolidated financial statements.
51
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"). 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 International is also the parent company of Edison Energy Group, a company
that holds interests in subsidiaries that are engaged in competitive businesses focused on providing energy services to
commercial and industrial customers, including distributed resources, engaging in competitive transmission opportunities,
and exploring distributed water treatment and recycling. Such competitive 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 nonutility 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. SCE
assesses, at the end of each reporting period, whether regulatory assets are probable of future recovery. See Note 10 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. Furthermore, certain prior year amounts
have been reclassified for consistency with the current period presentation. The proceeds from the sales and purchases of
nuclear decommissioning trust investments in the consolidated statement of cash flows of Edison International and SCE net
quick turnaround investment activity in the amount of $13.7 billion, $7.5 billion, and $4.4 billion for the years ended
December 31, 2015, 2014 and 2013, respectively.
Cash Equivalents
Cash equivalents includes 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,
2015
2014
2015
2014
$
37
$
35
$
8
$
5
52
Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are
reclassified from cash to accounts payable at the end of each reporting period as follows:
Edison International
SCE
December 31,
(in millions)
Book balances reclassified to accounts payable
2015
2014
2015
2014
$
162
$
180
$
158
$
177
Allowance for Uncollectible Accounts
Allowances for uncollectible accounts are provided based upon a variety of factors, including historical amounts written-off,
current economic conditions and assessment of customer collectability.
Inventory
Inventory is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being
determined by the average cost method.
Energy Credits and Allowances
Renewable energy certificates or credits ("RECs") represent rights established by governmental agencies for the
environmental, social, and other non-power qualities of renewable electricity generation. A REC, and its associated attributes
and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation
source in certain markets, including California. Retail sellers of electricity obtain RECs through renewable power purchase
agreements, internal generation or separate purchases in the market to comply with renewables portfolio standards ("RPS")
established by certain governmental agencies. RECs are the mechanism used to verify renewables portfolio standard
compliance and are recognized at the lower of weighted-average cost or market when amounts purchased are in excess of the
amounts needed to comply with RPS requirements. The cost of purchased RECs is recoverable as part of the cost of
purchased power.
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 of $79 million and $204 million at December 31, 2015 and 2014, respectively. GHG emission
obligations were $86 million and $211 million at December 31, 2015 and 2014, respectively and are classified as "Other
current liabilities" on the consolidated balance sheets.
Property, Plant and Equipment
Plant additions, including replacements and betterments, are capitalized. SCE capitalizes as part of plant additions direct
material and labor and indirect costs such as construction overhead, administrative and general costs, pension and benefits,
and property taxes. The CPUC authorizes a 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) 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
Weighted-Average
Useful Lives
38 years
43 years
52 years
22 years
Estimated Useful Lives
10 years to 57 years
20 years to 60 years
40 years to 65 years
5 years to 60 years
53
Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. Depreciation
expense was $1.42 billion, $1.33 billion and $1.31 billion for 2015, 2014 and 2013, respectively. Depreciation expense stated
as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.9%, 4.0% and 4.2% for 2015,
2014 and 2013, respectively. Replaced or retired property costs are charged to accumulated depreciation.
Nuclear fuel for the Palo Verde Nuclear Power Plant 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. Nuclear fuel is
amortized using the units of production method.
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 $87 million, $65 million and $72 million in 2015,
2014 and 2013, respectively. AFUDC debt was $31 million, $25 million and $33 million in 2015, 2014 and 2013,
respectively.
Major Maintenance
Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred.
Impairment of Long-Lived Assets
Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated
whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be
recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without
interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair
value is determined via market, cost and income based valuation techniques, as appropriate. SCE's impaired assets are
recorded as a regulatory asset if it is deemed probable that such amounts will be recovered from customers.
Due to the decision to early retire San Onofre Units 2 and 3, GAAP required reclassification of the amounts recorded in
property, plant and equipment and related tangible operating assets to a regulatory asset to the extent that management
concluded it was probable of recovery through future rates. Regulatory assets may also be recorded to the extent management
concludes it is probable that direct and indirect costs incurred to retire Units 2 and 3 as of each reporting date are recoverable
through future rates. In accordance with these requirements and as a result of its decision to retire San Onofre Units 2 and 3,
SCE reclassified $1,521 million of its total investment in San Onofre at May 31, 2013 to a regulatory asset ("San Onofre
Regulatory Asset") and recorded an impairment charge of $575 million ($365 million after-tax) in the second quarter of 2013.
In March 2014, SCE entered into a settlement agreement with The Utility Reform Network ("TURN"), the CPUC's Office of
Ratepayer Advocates ("ORA"), SDG&E, the Coalition of California Utility Employees, and Friends of the Earth (together,
the "Settling Parties"). In September 2014, SCE and the Settling Parties entered into an Amended and Restated Settlement
Agreement (the "San Onofre OII Settlement Agreement") which was approved by the CPUC on November 20, 2014. As a
result of these developments, SCE recorded an additional pre-tax charge of approximately $163 million (approximately
$72 million after-tax) during 2014. Including amounts previously recorded in 2013, the total impact of the San Onofre OII
Settlement Agreement was a pre-tax charge of $738 million (approximately $437 million after-tax). See Note 11 for further
information.
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.
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. SCE adjusts its nuclear decommissioning obligation
into a nuclear-related ARO regulatory asset and also 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 discussion, see
Notes 9 and 10.
54
The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde:
(in millions)
Beginning balance
Accretion1
Revisions
Liabilities settled
Ending balance
December 31,
2015
2014
$
$
2,819
173
(14)
(216)
2,762
$
$
3,418
192
(790)
(1)
2,819
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.
SCE has not recorded an asset retirement obligation for assets that are expected to operate indefinitely. As SCE cannot
estimate a settlement date (or range of potential settlement dates) or make reasonable estimates of fair value of these assets.
As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities.
Decommissioning costs, which are recovered through non-bypassable 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. Amortization of the ARO asset (included within the unamortized nuclear investment) and accretion of the ARO
liability are deferred as increases to the ARO regulatory liability account, resulting in no impact on earnings.
SCE has collected in rates amounts for the future costs of removal of its nuclear assets, and has placed those amounts in
independent trusts. The cost of removal amounts, in excess of amounts collected for assets not legally required to be
removed, are classified as regulatory liabilities.
The recorded liability to decommission SCE's nuclear power facilities is $2.7 billion as of December 31, 2015, based on
decommissioning studies performed in 2010 for Palo Verde, in 2011 for San Onofre Unit 1 and in 2014 for San Onofre
Units 2 and 3 following the decision to permanently retire San Onofre. During 2014, an updated cost estimate for San Onofre
Units 2 and 3 resulted in a decrease to the ARO liability of $688 million. In December 2014, SCE received a decision on its
NDCTP for Palo Verde and San Onofre Unit 1. The decision resulted in a $253 million decrease for Palo Verde and
$124 million increase for San Onofre Unit 1 ARO 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
$7.2 billion through 2075 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost
methodology used for ratemaking purposes, escalated at rates ranging from 1.4% to 7.3% (depending on the cost element)
annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax
earnings on the decommissioning funds of 3.3% to 4.1%. If the assumed return on trust assets is not earned or costs escalate
at higher rates, it is probable that additional funds needed for decommissioning will be recoverable through rates in the
future.
Decommissioning expense amounts collected in rates were $5 million in 2014 and $22 million in 2013. Total expenditures
for the decommissioning of San Onofre Unit 1 were $484 million (SCE's share) from the beginning of the project in 1998
through December 31, 2015.
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 tri-annual regulatory proceeding. SCE's nuclear decommissioning trust investments primarily consist of debt and
equity investments that are classified as available-for-sale. Due to regulatory mechanisms, earnings and realized gains and
losses (including other-than-temporary impairments) have no impact on electric utility revenue. Unrealized gains and losses
on decommissioning trust funds 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 security for other-than-temporary
impairment on the last day of each month. If the fair value on the last day of two consecutive months is less than the cost for
that security, SCE recognizes a loss for the other-than-temporary impairment. If the fair value is greater or less than the cost
for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively.
55
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 $201 million for both December 31, 2015 and 2014 reflected as long-term "Regulatory assets" in the consolidated
balance sheets. Edison International and SCE had unamortized debt issuance costs of $92 million and $84 million at
December 31, 2015, respectively, and $83 million and $75 million at December 31, 2014, respectively, reflected in "Other
long-term assets" on the consolidated balance sheets. Amortization of deferred financing costs charged to interest expense is
as follows:
(in millions)
2015
2014
2013
2015
Edison International
Years ended December 31,
SCE
2014
2013
Amortization of deferred financing
costs charged to interest expense
Revenue Recognition
$
33
$
36
$
33
$
28
$
32
$
32
Revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the end of
each reporting period and reflected in "Operating revenue" on the consolidated statements of income. Rates charged to
customers are based on CPUC- and FERC-authorized revenue requirements. CPUC rates are implemented subsequent to final
approval.
CPUC rates decouple authorized revenue from the volume of electricity sales. Differences between amounts collected and
authorized levels are either collected from or refunded to customers, and therefore, SCE earns revenue equal to amounts
authorized. FERC rates also decouple revenue from volume of electricity sales. In November 2013, the FERC approved a
formula rate effective January 1, 2012 to determine SCE's FERC transmission revenue requirement, including its construction
work in progress ("CWIP") revenue requirement. Under operation of the formula rate, transmission revenue will be updated
to actual cost of service annually. Differences between amounts collected and determined under the formula rate are either
collected from or refunded to customers, and therefore, SCE earns revenue based on estimates of recorded rate base costs
under the FERC formula rate.
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 and reflected in electric utility revenue and other operation and maintenance expense. SCE's franchise fees
billed to customers and recorded as revenue were $138 million, $134 million and $116 million in 2015, 2014 and 2013,
respectively. When SCE bills and collects taxes from customers, these taxes are remitted to the taxing authorities and are not
recognized as electric utility revenue.
Power Purchase Agreements
SCE enters into power purchase agreements in the normal course of business. A power purchase agreement may be
considered a variable interest in a variable interest entity. Under this classification, the power purchase agreement is
evaluated to determine if SCE is the primary beneficiary in the variable interest entity, in which case, such entity would be
consolidated. None of SCE's power purchase agreements resulted in consolidation of a variable interest entity at
December 31, 2015 and 2014. See Note 3 for further discussion of power purchase agreements that are considered variable
interests.
A power purchase agreement may also contain a lease for accounting purposes. This generally occurs when a power purchase
agreement (signed or modified after June 30, 2003) designates a specific power plant in which the buyer purchases
substantially all of the output and does not otherwise meet a fixed price per unit of output exception. SCE has a number of
power purchase agreements that contain leases. SCE's recognition of lease expense conforms to the ratemaking treatment for
SCE's recovery of the cost of electricity and is recorded in purchased power. The majority of these agreements are classified
as leases as electricity is delivered at rates defined in power sales agreements. See Note 11 for further discussion of SCE's
power purchase agreements, including agreements that are classified as operating and capital leases for accounting purposes.
56
A power purchase agreement that does not contain a lease may be classified as a derivative subject to a normal purchase and
sale exception, in which case the power purchase agreement is classified as an executory contract and accounted for on an
accrual basis. Most of SCE's QF contracts are not required to be recorded on the consolidated balance sheets because they
either do not meet the definition of a derivative or meet the normal purchase and sale exception. SCE purchases power under
certain contracts that are not eligible for the normal purchase and sale exception and are recorded as a derivative on the
consolidated balance sheets at fair value. See Note 6 for further information on derivative instruments.
Power purchase agreements 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
SCE enters into power purchase agreements that may contain leases, as discussed under "Power Purchase Agreements"
above. SCE has also entered into a number of agreements to lease property and equipment in the normal course of business.
Minimum lease payments under operating leases are levelized (total minimum lease payments divided by the number of
years of the lease) and recorded as rent expense over the terms of the leases. Lease payments in excess of the minimum are
recorded as rent expense in the year incurred.
Capital leases are reported as long-term obligations on the consolidated balance sheets in "Other deferred credits and other
long-term liabilities." As a rate-regulated enterprise, SCE's capital lease amortization expense and interest expense are
reflected in "Purchased power and fuel" on the consolidated statements of income.
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. Generally, Edison International does not issue new common
stock for settlement of equity awards. Rather, a third party is used to purchase shares from the market and delivery for
settlement of option exercises, performance shares and restricted stock units. Performance shares earned are settled half in
cash and half in common stock; however, Edison International has discretion under certain of the awards to pay the half
subject to cash settlement in common stock. Deferred stock units granted to management are settled in cash and represent a
liability. Restricted stock units are settled in common stock; however, Edison International will substitute cash awards to the
extent necessary to pay tax withholding or any government levies.
Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. For awards granted
to retirement-eligible participants stock compensation expenses are recognized on a prorated basis over the initial year or
over the period between the date of grant and the date the participant first becomes eligible for retirement.
Tax benefits related to stock-based compensation are recognized as a reduction to deferred taxes until the related tax
deductions reduce current income taxes. When such event occurs, the tax benefits are then recognized through additional paid
in capital. SCE allocates the tax benefits based on the provisions in the tax laws that identify the sequence in which the
amounts are utilized for tax purposes.
57
SCE Dividend Restrictions
The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make
distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above
48% on a 13-month weighted average basis. At December 31, 2015, SCE's 13-month weighted-average common equity
component of total capitalization was 49.9% and the maximum additional dividend that SCE could pay to Edison
International under this limitation was approximately $441 million. The remaining $13.2 billion of SCE's net assets are
restricted.
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, including performance shares and
restricted stock units, which earn dividend equivalents on an equal basis with common shares once the awards are vested.
EPS attributable to Edison International common shareholders was computed as follows:
(in millions)
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common
shareholders
Participating securities dividends
$
Income from continuing operations available to common shareholders $
Weighted average common shares outstanding
Basic earnings per share – continuing operations
$
Diluted earnings per share – continuing operations:
Income from continuing operations available to common shareholders $
Income impact of assumed conversions
Income from continuing operations available to common shareholders
and assumed conversions
Weighted average common shares outstanding
Incremental shares from assumed conversions
Adjusted weighted average shares – diluted
Diluted earnings per share – continuing operations
$
$
Years ended December 31,
2015
2014
2013
985
(1)
984
326
3.02
984
1
985
326
3
329
2.99
$
$
$
$
$
$
1,427
(1)
1,426
326
4.38
1,426
1
1,427
326
3
329
4.33
$
$
$
$
$
$
879
—
879
326
2.70
879
1
880
326
3
329
2.67
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
2,046,045, 125,345 and 3,977,894 shares of common stock for the years ended December 31, 2015, 2014 and 2013,
respectively, were outstanding, but were not included in the computation of diluted earnings per share because the exercise
price of the awards was greater than the average market price of the common shares during the respective periods and,
therefore, 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. Investment tax credits are deferred and amortized to income tax expense
over the lives of the properties or the term of the power purchase agreement of the respective project while production tax
credits are recognized in income tax expense in the period in which they are earned.
Interest income, interest expense and penalties associated with income taxes are reflected in "Income tax expense" on the
consolidated statements of income.
58
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.
Redeemable Noncontrolling Interest
Redeemable noncontrolling interest represents the portion of equity ownership in an entity that is not attributable to the
equity holders of Edison International and which have rights to put their ownership back to a subsidiary of Edison
International. Noncontrolling interest is initially recorded at fair value and is subsequently adjusted for income allocated to
the noncontrolling interest and any distributions paid to the noncontrolling interest.
Certain solar projects for commercial customers are organized as limited liability companies and have a noncontrolling equity
investor (referred to as tax equity investor) which is entitled to allocations of earnings, tax attributes and cash flows in
accordance with contractual agreements that vary over time. This entity is consolidated for financial reporting purposes but is
not subject to income taxes as the taxable income (loss) and investment tax credits are allocated to the respective owners. The
total assets and liabilities of this entity consolidated at December 31, 2015 were $82 million and $32 million, respectively.
Income (loss) of this entity is allocated to the noncontrolling interest based on the hypothetical liquidation at book value
("HLBV") accounting method. The HLBV accounting method is an approach that calculates the change in the claims of each
member on the net assets of the investment at the beginning and end of each period. Each member’s claim is equal to the
amount each party would receive or pay if the net assets of the investment were to liquidate at book value. Under the contract
provisions, the tax equity investor’s claim on net assets decreases rapidly in early years due to allocation of tax benefits
resulting in additional non-operating income allocated to Edison International ($16 million in 2015).
During 2014, indirect subsidiaries of Edison Energy Group entered into three non-recourse debt and tax equity financings
designed to fund significantly all of their capital requirements for approximately 29 MW solar rooftop projects. In the third
quarter of 2015, the borrowings under this financing agreement, were converted to a 7-year term loan. The tax equity
investors in these solar projects receive 99% of taxable profits and losses and tax credits of the projects as determined for
Federal income tax purposes for a six-year period following the completion of the portfolio of projects and receive a priority
return of 2% of their investment per year. After the six-year period, the tax equity investor receives 5% of the taxable profits
and losses and cash flow. A subsidiary of Edison International has a call option for a nine-month period following five years
after completion of the portfolio of projects to purchase the tax equity investors interest at fair value as defined in the
applicable agreement and the tax equity investor has the right to put its ownership interest to such subsidiary in the event that
the call option is not exercised.
New Accounting Guidance
Accounting Guidance Adopted
On November 20, 2015, the FASB issued an accounting standards update on the balance sheet classification of deferred
taxes. This standard requires that all deferred income tax assets and liabilities be presented as noncurrent in the consolidated
balance sheet. Prior to this update, deferred income taxes for each tax-paying component of an entity would be presented in
two classifications in the balance sheet: (1) a net current asset or liability and (2) a net noncurrent asset or liability. Edison
International and SCE have retrospectively adopted this standard as of December 31, 2015. As a result of the adoption,
Edison International reclassified $452 million of current deferred income tax assets to long-term deferred income tax
liabilities on the 2014 consolidated balance sheet. SCE reclassified $209 million of current deferred income tax liabilities to
long-term deferred income tax liabilities on the 2014 consolidated balance sheet.
Accounting Guidance Not Yet Adopted
On May 28, 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures.
Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer
obtains control of the good or service. On July 9, 2015, the FASB approved a one-year deferral, updating the effective date to
January 1, 2018. The accounting standard update allows for the adoption using a retrospective application or a modified
retrospective application. Edison International and SCE are currently evaluating this new guidance and cannot determine the
impact of this standard at this time. Edison International and SCE anticipates adopting the standard using the modified
retrospective application which means that we would recognize the cumulative effect of initially applying the revenue
standard as an adjustment to the opening balance of retained earnings in 2018.
59
On April 7, 2015, the FASB issued an accounting standards update that will require debt issuance costs to be presented in the
balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts.
Currently, these costs are presented as a deferred charge asset. Edison International and SCE will adopt this guidance in the
first quarter of 2016. The adoption of this accounting standards update will not have a material impact on Edison
International's and SCE's consolidated financial statements.
On April 15, 2015, the FASB issued an accounting standard update on fees paid by a customer for software licenses. This
new standard provides guidance about whether a cloud computing arrangement includes a software license which may be
capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the
arrangement should be accounted for as a service contract. Edison International and SCE will adopt this guidance
prospectively, effective January 1, 2016. The adoption of this standard will not have a material impact on Edison
International's and SCE's consolidated financial statements.
On January 5, 2016, the FASB issued an accounting standards update that amends the guidance on the classification and
measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the
equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net
income. Currently, these changes are recorded in other comprehensive income. It also amends certain disclosure requirements
associated with the fair value of financial instruments. In addition, the new guidance requires financial assets and financial
liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of
financial asset. Edison International and SCE will adopt this guidance effective January 1, 2018. The adoption of this
standard is not expected to have a material impact on Edison International's and SCE's consolidated financial statements.
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)
Transmission
Distribution
Generation
General plant and other
Accumulated depreciation
Construction work in progress
Nuclear fuel, at amortized cost
$
December 31,
2015
2014
$
11,592
20,871
3,138
4,543
(8,548)
31,596
3,218
131
10,391
19,255
2,986
4,889
(8,132)
29,389
3,339
131
Total utility property, plant and equipment
$
34,945
$
32,859
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, ranging from 5 to
15 years and commencing upon operational use. At December 31, 2015 and 2014, capitalized software costs included in
general plant and other above, were $1.4 billion and $1.7 billion and accumulated amortization was $892 million and
$1.0 billion, respectively. Amortization expense for capitalized software was $268 million, $271 million and $251 million in
2015, 2014 and 2013, respectively. At December 31, 2015, amortization expense is estimated to be approximately
$237 million annually for 2016 through 2020.
Jointly Owned Utility Projects
SCE owns undivided interests in several 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. A portion of the
investments in Palo Verde generating stations is included in regulatory assets on the consolidated balance sheets. For further
information see Note 10.
60
The following is SCE's investment in each asset as of December 31, 2015:
(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
$
$
186 $
191
38 $
11
20 $
79
1,928
2,305 $
62
111 $
1,538
1,637 $
— $
—
131
131 $
204
123
583
910
59%
50%
16%
In addition, SCE has ownership interests in jointly owned power poles with other companies.
Note 3. Variable Interest Entities
A variable interest entity ("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. A subsidiary of Edison International is the primary beneficiary of an entity that owns rooftop solar
projects (for further information, see Note 1—Redeemable Noncontrolling Interests). 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 Contracts
SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements
through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities ("QFs") that contain
variable pricing provisions based on the price of natural gas. 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 sheet that relate to its
involvement with VIEs result from amounts due under the PPAs or the fair value of those derivative contracts. 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 11. 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 4,062 MW and
5,641 MW at December 31, 2015 and 2014, respectively, and the amounts that SCE paid to these projects were $640 million
and $739 million for the years ended December 31, 2015 and 2014, respectively. These amounts are recoverable in customer
rates, subject to reasonableness review.
61
Unconsolidated Trusts of SCE
SCE Trust I, Trust II, Trust III and Trust IV were formed in 2012, 2013, 2014 and 2015 respectively, for the exclusive
purpose of issuing the 5.625%, 5.10%, 5.75% and 5.375% 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 I, Trust II, Trust III and
Trust IV issued trust securities in the face amount of $475 million, $400 million, $275 million and $325 million, respectively,
(cumulative, liquidation amount of $25 per share) to the public and $10,000 of common stock each to SCE. The trusts
invested the proceeds of these trust securities in Series F, Series G, Series H and Series J Preference Stock issued by SCE in
the principal amount of $475 million, $400 million, $275 million and $325 million (cumulative, $2,500 per share liquidation
value), respectively, which have substantially the same payment terms as the trust securities.
The Series F, Series G, Series H and Series J Preference Stock and the corresponding trust securities do not have a maturity
date. Upon any redemption of any shares of the Series F, Series G, Series H or Series J Preference Stock, a corresponding
dollar amount of trust securities will be redeemed by the applicable trust (see Note 12 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 when and if the
SCE board of directors declares and makes dividend payments on the related Preference Stock. The applicable trusts 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.
The Trust I, Trust II and Trust III balance sheets as of December 31, 2015, and 2014 consisted of investments of
$475 million, $400 million and $275 million in the Series F, Series G and Series H Preference Stock respectively,
$475 million, $400 million and $275 million of trust securities, respectively and $10,000 each of common stock. The Trust
IV balance sheet as of December 31, 2015 consisted of investments of $325 million in the Series J Preference Stock,
$325 million of trust securities, and $10,000 of common stock.
The following table provides a summary of the trusts' income statements:
(in millions)
2015
Dividend income
Dividend distributions
2014
Dividend income
Dividend distributions
2013
Dividend income
Dividend distributions
Years ended December 31,
Trust I
Trust II
Trust III
Trust IV
$
$
$
$
$
$
27
27
27
27
27
27
$
$
20
20
20
20
19
19
$
16
16
13
13
*
*
6
6
*
*
*
*
* Not applicable
Note 4.
Fair Value Measurements
Recurring Fair Value Measurements
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction
between market participants at the measurement date (referred to as an "exit price"). Fair value of an asset or liability
considers assumptions that market participants would use in pricing the asset or liability, including assumptions about
nonperformance risk. As of December 31, 2015 and 2014, 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.
62
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 exchanges (New York Mercantile Exchange and 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 over-the-counter options, tolling
arrangements and derivative contracts that trade infrequently such as congestion revenue rights ("CRRs") and other power
agreements. 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. Changes in fair
value are based on changes to forward market prices, including extrapolation of short-term observable inputs into forecasted
prices for illiquid forward periods. In circumstances where fair value cannot be verified with observable market transactions,
it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling
methodologies, inputs and techniques are reviewed and assessed as markets continue to develop and more pricing
information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would
result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of fair
value 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 (liabilities)
December 31, 2015
Level 1
Level 2
Level 3
Netting
and
Collateral1
Total
$
— $
— $
28
1,460
947
91
2,498
2,526
—
—
—
—
1,776
81
1,857
1,857
22
22
$
2,526
$
1,835
$
63
163
—
—
—
—
—
163
$
— $
—
—
—
—
—
—
1,311
1,311
(1,148)
$
(15)
(15)
15
$
163
28
1,460
2,723
172
4,355
4,546
1,318
1,318
3,228
December 31, 2014
Level 1
Level 2
Level 3
Netting
and
Collateral1
Total
(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 (liabilities)
$
— $
— $
33
2,031
703
606
3,340
3,373
—
—
3,373
$
—
—
1,350
166
1,516
1,516
86
86
1,430
$
321
—
—
—
—
—
321
$
— $
—
—
—
—
—
—
1,223
1,223
(902)
$
$
(61)
(61)
61
$
321
33
2,031
2,053
772
4,856
5,210
1,248
1,248
3,962
1 Represents the netting of assets and liabilities under master netting agreements and cash collateral across the levels of the fair value
hierarchy. Netting among positions classified within the same level is included in that level.
2 Approximately 70% and 73% of SCE's equity investments were located in the United States at December 31, 2015 and 2014,
respectively.
3
Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of
$111 million and $49 million at December 31, 2015 and 2014, respectively.
4 Excludes net payables of $24 million and $57 million at December 31, 2015 and 2014, 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 consisted of money market funds of $29 million and
$30 million at December 31, 2015 and 2014, respectively, classified as Level 1.
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 liabilities at beginning of period
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities1
Purchases
Settlements
Fair value of net liabilities at end of period
Change during the period in unrealized gains and losses related to assets and liabilities
held at the end of the period
December 31,
2015
2014
(902)
$
(805)
(246)
—
—
(1,148)
(311)
$
$
(97)
27
(27)
(902)
(166)
$
$
$
1 Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities.
Edison International and SCE recognize the fair value for transfers in and transfers out of each level at the end of each
reporting period. There were no significant transfers between any levels during 2015 and 2014.
64
Valuation Techniques Used to Determine Fair Value
The process of determining fair value is the responsibility of SCE's risk management department, which report to SCE's chief
financial officer. This department obtains observable and unobservable inputs through broker quotes, exchanges and internal
valuation techniques that use both standard and proprietary models to determine fair value. Each reporting period, the risk
and finance departments collaborate to determine the appropriate fair value methodologies and classifications for each
derivative. Inputs are validated for reasonableness by comparison against prior prices, other broker quotes and volatility
fluctuation thresholds. Inputs used and valuations are reviewed period-over-period and compared with market conditions to
determine reasonableness.
The following table sets forth SCE's valuation techniques and significant unobservable inputs used to determine fair value for
significant Level 3 assets and liabilities:
Fair Value (in millions)
Significant
Range
Assets
Liabilities
Valuation Technique(s)
Unobservable Input
(Weighted Average)
Congestion revenue rights
December 31, 2015
$
152
$
—
Market simulation model
and auction prices
December 31, 2014
317
Market simulation model
and auction prices
—
Load forecast
Power prices1
Gas prices2
Load forecast
Power prices1
Gas prices2
6,289 MW - 24,349 MW
$0 - $110.44
$1.98 - $5.72
7,630 MW - 25,431 MW
$1.65 - $109.95
$3.65 - $6.53
Tolling
December 31, 2015
10
1,297 Option model
Volatility of gas prices
15% - 58% (20%)
December 31, 2014
4
1,207 Option model
Volatility of gas prices
13% - 53% (20%)
Volatility of power prices
25% - 42% (30%)
Power prices
$30.60 - $61.40 ($44.60)
Volatility of power prices
26% - 38% (30%)
Power prices
$24.15 - $46.93 ($34.80)
1 Prices are in dollars per megawatt-hour.
2 Prices are in dollars per million British thermal units.
Level 3 Fair Value Sensitivity
Congestion Revenue Rights
For CRRs, where SCE is the buyer, generally increases (decreases) in forecasted load in isolation would result in increases
(decreases) to the fair value. In general, an increase (decrease) in electricity and gas prices at illiquid locations tends to result
in increases (decreases) to fair value; however, changes in electricity and gas prices in opposite directions may have varying
results on fair value.
Tolling Arrangements
The fair values of SCE's tolling arrangements contain intrinsic value and time value. Intrinsic value is the difference between
the market price and strike price of the underlying commodity. Time value is made up of several components, including
volatility, time to expiration, and interest rates. The option model for tolling arrangements reflects plant specific information
such as operating and start-up costs.
For tolling arrangements where SCE is the buyer, increases in volatility of the underlying commodity prices would result in
increases to fair value as it represents greater price movement risk. As power and gas prices increase, the fair value of tolling
arrangements tends to increase. The valuation of tolling arrangements is also impacted by the correlation between gas and
power prices. As the correlation increases, the fair value of tolling arrangements tends to decline.
65
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.
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. A primary price source is identified by the trustee based on asset type, class or issue for each
security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the
primary price source of a given security if the trustee or SCE's investment managers challenge an assigned price and
determine that another price source is considered to be preferable. Parameters and predetermined tolerance thresholds are
established by asset class based on past experience and an understanding of valuation process techniques. The trustee
"scrubs" prices against defined parameters' tolerances and performs research and resolves variances beyond the set
parameters. SCE reviewed 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 and to reach a conclusion that their pricing
controls are satisfactory. This consisted of SCE's review of their written detailed process/procedures and service organization
control reports, as well as follow-up conversations based on our written questions. This assists SCE in determining if the
valuations represent exit price fair value and that investments are appropriately classified in the fair value hierarchy.
Additionally, 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. The
results of this process have demonstrated that vendor and trustee pricing controls are satisfactory. For each reporting period,
SCE reviews the trustee determined fair value hierarchy and overrides the trustee level classification when appropriate.
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, 2015
December 31, 2014
Carrying
Value
Fair
Value
Carrying
Value
$
$
11,259
10,616
12,252
11,592
$
10,738
$
9,924
Fair
Value
12,319
11,479
The fair value of Edison International's and SCE's short-term and long-term debt is classified as Level 2 and 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 of new issue prices and relevant credit information.
The carrying value of Edison International's and SCE's trade receivables and payables, other investments, and short-term debt
approximates fair value.
66
Note 5. Debt and Credit Agreements
Long-Term Debt
The following table summarizes long-term debt (rates and terms are as of December 31, 2015) of Edison International and
SCE:
(in millions)
Edison International Parent and Other:
Debentures and notes:
2016 – 2017 (0% to 3.75%)
Other long-term debt
Current portion of long-term debt
Unamortized debt discount, net
Total Edison International Parent and Other
SCE:
First and refunding mortgage bonds:
2017 – 2045 (1.125% to 6.05%)
Pollution-control bonds:
2028 – 2035 (1.375% to 5.0% and variable)1
Debentures and notes:
2029 – 2053 (5.06% to 6.65%)
Current portion of long-term debt
Unamortized debt discount, net
Total SCE
Total Edison International
December 31,
2015
2014
$
$
614
31
(216)
(2)
427
9,436
909
307
(79)
(36)
10,537
10,964
$
$
817
2
(204)
(5)
610
8,875
779
307
(300)
(37)
9,624
10,234
1
Includes outstanding bonds that have not been retired and may be remarketed to investors in the future. These
bonds have variable rates and are due in 2031 at December 31, 2015.
Edison International and SCE long-term debt maturities over the next five years are the following:
(in millions)
2016
2017
2018
2019
2020
$
Edison
International
295
903
402
2
1
SCE
$
79
500
400
—
—
During the first quarter of 2015, SCE issued $550 million of 1.845% amortizing first and refunding mortgage bonds due in
2022, $325 million of 2.4% first and refunding mortgage bonds due in 2022, and $425 million of 3.6% first and refunding
mortgage bonds due in 2045. The proceeds from these bonds were used to repay outstanding debt and for general corporate
purposes. The $550 million amortizing first and refunding mortgage bonds and the $325 million of first and refunding
mortgage bonds have been designated as a financing of the San Onofre regulatory asset.
During the second quarter of 2015, SCE reissued $56 million of 1.875% pollution-control bonds due in 2029 and $75 million
of 1.875% pollution-control bonds due in 2031. The proceeds were used to repay commercial paper borrowings and for
general corporate purposes.
67
Project Financings
Indirect subsidiaries of Edison International entered into a non-recourse debt financing to support investment in
approximately 29 megawatts of solar rooftop projects. Borrowings under this financing agreement, were converted to a
7-year term loan during September 2015. As of December 31, 2015, there was approximately $25 million outstanding under
this financing at a weighted average interest rate of 3.11% which is classified as long-term debt. As of December 31, 2014,
there was $5.1 million outstanding under this financing at a weighted average interest rate of 2.67% which was classified as
short-term debt.
During 2014, an indirect subsidiary of Edison International entered into an $80 million non-recourse debt financing to
support equity contributions in solar projects. The maturity date of any borrowings under this agreement is December 31,
2036. As of December 31, 2015, there was $6 million outstanding under this agreement at a weighted average interest rate of
9%. At December 31, 2014, there were no loans outstanding under this agreement.
Liens and Security Interests
Almost all of SCE's properties are subject to a trust indenture lien. SCE has pledged first and refunding mortgage bonds as
collateral for borrowed funds obtained from pollution-control bonds issued by government agencies. SCE has a debt
covenant that requires a debt to total capitalization ratio be met. At December 31, 2015, SCE was in compliance with this
debt covenant.
All of the properties subject to the Edison Energy Group project financings discussed above are subject to a lien.
Credit Agreements and Short-Term Debt
The following table summarizes the status of the credit facilities at December 31, 2015:
(in millions)
Commitment
Outstanding borrowings
Outstanding letters of credit
Amount available
Edison
International
Parent
$
$
$
1,250
(646)
—
604
$
SCE
2,750
(49)
(125)
2,576
SCE and Edison International have multi-year revolving credit facilities of $2.75 billion and $1.25 billion, with both
maturing in July 2020. SCE's credit facility is generally used to support commercial paper borrowings and letters of credit
issued for procurement-related collateral requirements, balancing account undercollections and for general corporate
purposes, including working capital requirements to support operations and capital expenditures. Edison International
Parent's credit facility is used to support commercial paper borrowings and for general corporate purposes.
At December 31, 2015, commercial paper supported by SCE's credit facility was $49 million at a weighted-average interest
rate of 0.51%. At December 31, 2015, letters of credit issued under SCE's credit facility aggregated $125 million and are
scheduled to expire in twelve months or less. At December 31, 2014, the outstanding commercial paper was $367 million at a
weighted-average interest rate of 0.40%.
At December 31, 2015, Edison International Parent's outstanding commercial paper was $646 million at a weighted-average
interest rate of 0.78%. This commercial paper was supported by the $1.25 billion multi-year revolving credit facility. At
December 31, 2014, the outstanding commercial paper was $619 million at a weighted-average interest rate of 0.45%.
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.
68
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 power
purchase agreements. SCE's natural gas price exposure arises from natural gas purchased for the Mountainview power plant
and peaker plants, QF contracts where pricing is based on a monthly natural gas index and power purchase agreements 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 contracts contain master netting agreements or similar agreements, which generally allow counterparties
subject to the agreement to setoff 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 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 $38 million and
$53 million as of December 31, 2015 and 2014, respectively, for which SCE has posted no collateral and $13 million of
collateral to its counterparties at December 31, 2015 and 2014, respectively. If the credit-risk-related contingent features
underlying these agreements were triggered on December 31, 2015, SCE would be required to post $22 million of additional
collateral of which $8 million is related to outstanding payables that are net of collateral already posted.
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 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:
(in millions)
Short-Term Long-Term
Subtotal
Short-Term Long-Term
Subtotal
December 31, 2015
Derivative Assets
Derivative Liabilities
Net
Liability
Commodity derivative contracts
Gross amounts recognized
Gross amounts offset in
consolidated balance
sheets
Cash collateral posted1
Net amounts presented in the
consolidated balance sheets
$
81
$
84
$
165
$
235
$
1,100
$
1,335
$
1,170
(2)
—
—
—
(2)
—
(2)
(15)
—
—
(2)
(15)
—
(15)
$
79
$
84
$
163
$
218
$
1,100
$
1,318
$
1,155
69
(in millions)
Short-Term Long-Term
Subtotal
Short-Term Long-Term
Subtotal
December 31, 2014
Derivative Assets
Derivative Liabilities
Net
Liability
Commodity derivative contracts
Gross amounts recognized
Gross amounts offset in
consolidated balance
sheets
Cash collateral posted1
Net amounts presented in the
consolidated balance sheets
$
104
$
219
$
323
$
259
$
1,052
$
1,311
$
988
(2)
—
—
—
(2)
—
(2)
(61)
—
—
(2)
(61)
—
(61)
$
102
$
219
$
321
$
196
$
1,052
$
1,248
$
927
1
In addition, at December 31, 2015 and 2014, SCE had posted $31 million and $36 million, respectively, of collateral that is not offset
against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets.
Income 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 purchase 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 recorded in cash flows from operating activities in the consolidated
statements of cash flows.
The following table summarizes the components of SCE's economic hedging activity:
(in millions)
Realized losses
Unrealized (losses) gains
Notional Volumes of Derivative Instruments
Years ended December 31,
2015
2014
2013
$
$
(148)
(182)
$
(57)
(147)
(56)
93
The following table summarizes the notional volumes of derivatives used for SCE hedging activities:
Commodity
Electricity options, swaps and forwards
Natural gas options, swaps and forwards
Congestion revenue rights
Tolling arrangements
Note 7.
Income Taxes
Current and Deferred Taxes
Unit of
Measure
GWh
Bcf
GWh
GWh
Economic Hedges
December 31,
2015
2014
6,221
32
109,740
70,663
3,618
83
122,859
79,989
Edison International's sources of income (loss) before income taxes are:
(in millions)
Income from continuing operations before income taxes
Income (loss) from discontinued operations before income taxes
Income before income tax
Years ended December 31,
2015
2014
2013
$
$
1,568
15
1,583
$
$
1,979
(525)
1,454
$
$
1,221
—
1,221
70
The components of income tax expense (benefit) by location of taxing jurisdiction are:
(in millions)
Current:
Federal
State
Deferred:
Federal
State
Total continuing operations
Discontinued operations1
Total
Edison International
2015
2014
2013
2015
Years ended December 31,
SCE
2014
2013
$
$
18
19
37
340
109
449
486
(21)
465
$
$
(99)
20
(79)
454
68
522
443
(710)
(267)
$
$
(97)
(9)
(106)
317
31
348
242
(36)
206
$
$
72
127
199
298
10
308
507
—
507
$
$
(89)
101
12
476
(14)
462
474
—
474
$
$
(119)
(19)
(138)
345
72
417
279
—
279
1 See Note 15 for a discussion of discontinued operations related to EME.
The components of net accumulated deferred income tax liability are:
Edison International
SCE
December 31,
2015
2014
2015
2014
$
675
$
572
$
675
$
571
360
1,388
21
337
499
3,280
32
3,248
9,606
207
202
360
71
189
10,635
7,387
$
441
1,657
18
510
582
3,780
29
3,751
8,709
285
577
441
227
274
10,513
6,762
$
360
—
21
154
411
1,621
—
1,621
9,600
207
202
360
71
161
10,601
8,980
$
441
205
18
321
445
2,001
—
2,001
8,699
285
577
441
227
171
10,400
8,399
(in millions)
Deferred tax assets:
Property and software related
Nuclear decommissioning trust assets in excess of
nuclear ARO liability
Loss and credit carryforwards
Regulatory balancing accounts
Pension and PBOPs
Other
Sub-total
Less valuation allowance
Total
Deferred tax liabilities:
Property-related
Capitalized software costs
Regulatory balancing accounts
Nuclear decommissioning trust assets
PBOPs
Other
Total
Accumulated deferred income tax liability, net1
$
1 Included in deferred income taxes and credits.
71
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 between 2021 to 2034
No expiration date
Total1
Edison International
SCE
December 31, 2015
Loss
Carryforwards
Credit
Carryforwards
Loss
Carryforwards
Credit
Carryforwards
$
$
1,136
—
1,136
$
$
409
54
463
$
$
39
—
39
$
$
22
39
61
1 Deferred tax assets for net operating loss and tax credit carryforwards are reduced by unrecognized tax benefits of $211 million and
$100 million for Edison International and SCE, respectively.
Edison International has recorded a valuation allowance of $32 million for state net operating loss carryforwards estimated to
expire unused.
As of December 31, 2015, Edison International and SCE had federal net operating loss carryforwards related to the tax benefit
on employee stock plans that would be recorded to additional paid-in capital when realized for the amount of $42 million and
$6 million.
Edison International consolidates for federal income tax purposes a group of wind projects referred to as Capistrano Wind.
The amount of net operating loss and tax credit carryforwards recognized as part of deferred income taxes includes
$210 million related to Capistrano Wind. Under a tax allocation agreement, Edison International has recorded the 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 from continuing operations
before income taxes
Provision for income tax at federal
statutory rate of 35%
Increase in income tax from:
Items presented with related state
income tax, net:
Regulatory asset write-off1
State tax, net of federal benefit
Property-related2
Change related to uncertain tax
positions
San Onofre OII settlement
Other
Total income tax expense from
continuing operations
Effective tax rate
1 Includes federal and state.
Edison International
2015
2014
2013
2015
Years ended December 31,
SCE
2014
2013
$
1,568
$
1,979
$
1,221
$
1,618
$
2,039
$
1,279
549
693
427
566
714
448
382
5
(341)
(67)
—
(42)
—
56
(252)
5
(23)
(36)
—
18
(216)
14
24
(25)
382
34
(341)
(94)
—
(40)
—
55
(252)
12
(23)
(32)
—
34
(216)
14
24
(25)
$
$
486
31.0%
$
443
22.4%
$
242
19.8%
$
507
31.3%
$
474
23.2%
279
21.8%
2
Includes incremental repair benefit recorded in 2013 to 2015. See discussion of repair deductions below.
72
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.
Repair Deductions
Edison International made voluntary elections in 2009 and 2011 to change its tax accounting method for certain tax repair
costs incurred on SCE's transmission, distribution and generation assets. Incremental repair deductions represent amounts
recognized for regulatory accounting purposes in excess of amounts included in the authorized revenue requirements through
the General Rate Case ("GRC") proceedings. Incremental repair deductions for the years 2012 – 2014 resulted in additional
income tax benefits of $133 million in 2014 and $89 million in 2013.
As part of the final decision in SCE's 2015 GRC, the CPUC adopted a rate base offset associated with these incremental tax
repair deductions during 2012 – 2014. The 2015 rate base offset is $324 million and amortizes on a straight line basis over
27 years. As a result of the rate base offset included in the final decision, SCE recorded an after tax charge of $382 million
during the fourth quarter of 2015 to write down the net regulatory asset for recovery of deferred income taxes related to
2012 – 2014 incremental tax repair deductions which is reflected in "Income tax expense" on the consolidated statements of
income.
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 the available evidence indicates it
is more likely than not, based solely on the technical merits, that the position will be sustained upon examination. The
guidance requires the disclosure of all unrecognized tax benefits, which includes both the reserves recorded for tax positions
on filed tax returns and the unrecognized portion of affirmative claims.
Unrecognized Tax Benefits
The following table provides a reconciliation of unrecognized tax benefits for continuing and discontinued operations:
(in millions)
2015
2014
2013
2015
2014
2013
Balance at January 1,
$
576
$
815
$
812
$
441
$
532
$
571
Edison International
SCE
December 31,
Tax positions taken during the
current year:
Increases
Tax positions taken during a prior
year:
Increases
Decreases1
Increases – deconsolidation of
EME2
Decreases for settlements during
the period3
54
65
19
48
57
22
66
(165)
—
(2)
1
(143)
—
(162)
576
$
43
(109)
50
—
815
$
23
(159)
—
—
353
$
—
(93)
—
(55)
441
$
45
(106)
—
—
532
Balance at December 31,
$
529
$
1 Decreases in prior year tax positions relate primarily to re-measurement of uncertain tax positions in connection with receipt of the IRS
Revenue Agent Report in June 2015. See discussions in Tax Disputes below.
2 Unrecognized tax benefits of EME have been deconsolidated as a result of the bankruptcy filing by EME, except for tax liabilities for
which Edison International and EME are jointly liable under the Internal Revenue Code and applicable state statutes. See Note 15 for
further information. During 2013, Edison International increased the amount of unrecognized tax benefits related to the taxable gain on
sale of EME’s international assets by approximately $50 million as a result of unfavorable developments during the fourth quarter of
2013.
3 In the fourth quarter of 2014, Edison International has settled all open tax positions with the IRS for taxable year 2003 through 2006.
73
As of December 31, 2015 and 2014, if recognized, $440 million and $503 million respectively, of the unrecognized tax
benefits would impact Edison International's effective tax rate; and $256 million and $370 million, respectively, of the
unrecognized tax benefits would impact SCE's effective tax rate.
Tax Disputes
Tax Years 2007 – 2009
Edison International received a Revenue Agent Report from the IRS in February 2013 which included a proposed adjustment
to disallow deductions related to certain capitalized overhead costs. Edison International has tentatively reached an agreement
with the IRS regarding this matter, which if finalized, would result in a federal tax liability of approximately $64 million,
including interest through December 31, 2015.
Tax Years 2010 – 2012
The IRS Revenue Agent Report was received in June 2015. As a result, Edison International and SCE have re-measured its
Federal and State uncertain tax positions and recorded $94 million and $100 million, respectively, of income tax benefits
including interest and penalty during the second quarter of 2015. The Revenue Agent Report included a proposed adjustment
to disallow deductions related to certain capitalized overhead expenses. Edison International has tentatively reached an
agreement with the IRS regarding this matter, which if finalized, would result in a federal tax liability of approximately
$9 million, including interest through December 31, 2015.
Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2007 – 2015 and
2003 – 2015, respectively.
Accrued Interest and Penalties
The total amount of accrued interest and penalties related to income tax liabilities for continuing and discontinued operations
are:
(in millions)
Accrued interest and penalties
Edison International
SCE
2015
Years ended December 31,
2014
2015
2014
$
122
$
338
$
40
$
64
The net after-tax interest and penalties recognized in income tax expense for continuing and discontinued operations are:
(in millions)
2015
2014
2013
2015
Edison International
December 31,
SCE
2014
2013
Net after-tax interest and penalties
tax benefit (expense)
$
9
$
41
$
(3)
$
14
$
16
$
2
74
Note 8. Compensation and Benefit Plans
Employee Savings Plan
The 401(k) defined contribution savings plan is designed to supplement employees' retirement income. The following
employer contributions were made for continuing operations:
(in millions)
2015
2014
2013
Edison
International
SCE
Years ended December 31,
$
$
73
71
76
72
70
76
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. 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
$123 million and $94 million, respectively, for the year ending December 31, 2016. Annual contributions made by SCE to
most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms. Annual
contributions to these plans are expected to be, at a minimum, equal to the related annual expense.
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 1).
75
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 (gain) loss
Curtailment gain
Benefits paid
Other
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 of1:
Current liabilities
Long-term liabilities
Amounts recognized in accumulated other comprehensive loss
consist of:
Net loss1
Amounts recognized as a regulatory asset:
Prior service cost
Net loss
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
Weighted-average assumptions used to determine obligations at end
of year:
Discount rate
Rate of compensation increase
Edison International
SCE
Years ended December 31,
2015
2014
2015
2014
$
$
4,517
142
170
(149)
—
(305)
(1)
4,374
$
3,454
30
119
(305)
3,298
$
$ (1,076)
$
$
4,178
133
181
469
(5)
(449)
10
4,517
$
3,477
257
169
(449)
3,454
$
$ (1,063)
$
(27)
(1,049)
$ (1,076)
$
(27)
(1,036)
$ (1,063)
$
$
$
$
$
$
96
15
660
675
771
4,200
4,374
4,200
3,298
$
$
$
$
$
$
102
20
640
660
762
4,356
4,517
4,356
3,454
$
$
$
$
$
$
$
$
$
$
$
$
$
3,999
133
150
(143)
—
(261)
—
3,878
3,217
27
97
(261)
3,080
(798)
(4)
(794)
(798)
27
15
660
675
702
3,744
3,878
3,744
3,080
$
$
$
$
$
$
$
$
$
$
$
$
$
3,721
124
159
386
—
(391)
—
3,999
3,236
240
132
(391)
3,217
(782)
(5)
(777)
(782)
31
20
640
660
691
3,881
3,999
3,881
3,217
4.18%
4.00%
3.85%
4.00%
4.18%
4.00%
3.85%
4.00%
1 The SCE liability excludes a long-term payable due to Edison International Parent of $123 million and $121 million at December 31,
2015 and 2014, respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent. SCE's
accumulated other comprehensive loss of $27 million and $31 million at December 31, 2015 and 2014, respectively, excludes net loss
of $18 million and $22 million related to these benefits.
76
In 2015 and 2014, Edison International and SCE adopted new mortality tables that the Society of Actuaries released in
October each year that reflect changes in life expectancy. At December 31, 2015 and 2014, this adoption resulted in a change
in Edison International's pension plans' projected benefit obligation of $(34) million and $214 million, respectively, including
$(31) million and $199 million, respectively, for SCE.
Pension expense components for continuing operations are:
(in millions)
Service cost
Interest cost
Expected return on plan assets
Settlement costs1
Curtailment gain
Amortization of prior service cost
Amortization of net loss2
Expense under accounting standards
Regulatory adjustment (deferred)
$
142
170
(233)
—
—
5
40
124
(6)
Edison International
SCE
Years ended December 31,
2015
2014
2013
2015
2014
2013
$
133
$
162
$
139
$
128
$
181
(229)
45
(4)
5
12
143
8
170
(222)
87
—
5
39
241
(53)
188
$
155
(217)
—
—
5
35
117
(6)
111
164
(213)
42
—
5
7
133
8
$
141
$
159
167
(222)
85
—
5
35
229
(53)
176
Total expense recognized
$
118
$
151
$
1
2
Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International was zero
for the year ended December 31, 2015 and $3 million for the year ended December 31, 2014.
Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE
was $14 million and $8 million, respectively, for the year ended December 31, 2015. The amount reclassified for Edison International
and SCE was $9 million and $4 million, respectively, for the year ended December 31, 2014.
Under GAAP, a settlement is recorded when lump-sum payments exceed estimated annual service and interest costs. Lump-
sum payments to employees retiring in 2014 and 2013 from the SCE Retirement Plan (primarily due to workforce reductions
described below) exceeded the estimated service and interest costs for those years. A settlement requires re-measurement of
both the plan pension obligations and plan assets as of the date of the settlement. Re-measurement assumption changes result
in actuarial gains and losses which are combined with previous unrecognized gains and losses. After re-measurement, GAAP
requires an acceleration of a portion of unrecognized net losses attributable to such lump-sum payments as additional pension
expense as reflected in the above table. The additional pension expense related to SCE did not impact net income as such
amounts are probable of recovery through future rates.
The SCE Retirement Plan experienced total actuarial losses of $374 million, including $357 million for SCE during 2014.
The actuarial losses in 2014 were primarily due to a decrease in the discount rate (from 4.75% at December 31, 2013 to
4.00% as of August 31, 2014 and 3.85% as of December 31, 2014) due to lower interest rates.
Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing
operations:
(in millions)
Net loss (gain)
Amortization of net loss and other
Total recognized in other
comprehensive loss
Total recognized in expense and
other comprehensive loss
Edison International
SCE
Years ended December 31,
2015
2014
2013
2015
2014
2013
$
$
$
(33)
(13)
(46)
142
$
$
$
(9)
(9)
(18)
93
$
$
$
37
(4)
33
174
$
$
$
(24)
(7)
(31)
145
$
$
$
7
(15)
(8)
110
$
$
$
85
(13)
72
223
77
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. The estimated pension amounts that will be amortized to expense in 2016 for continuing
operations are as follows:
(in millions)
Unrecognized net loss to be amortized1
Unrecognized prior service cost to be amortized
Edison
International
SCE
$
$
36
4
32
4
1 The amount of net loss expected to be reclassified from other comprehensive loss for Edison International's continuing operations and
SCE is $11 million and $6 million, respectively.
Edison International and SCE used the following weighted-average assumptions to determine pension expense for continuing
operations:
Discount rate
Rate of compensation increase
Expected long-term return on plan assets
Years ended December 31,
2015
2014
2013
3.85%
4.00%
7.00%
4.50%
4.00%
7.00%
4.13%
4.50%
7.00%
The following benefit payments, which reflect expected future service, are expected to be paid:
(in millions)
2016
2017
2018
2019
2020
2021 – 2025
Edison
International
SCE
Years ended December 31,
$
$
311
310
314
327
327
265
270
280
286
290
1,590
1,447
Postretirement Benefits Other Than Pensions ("PBOP(s)")
Most employees retiring at or after age 55 with at least 10 years of service may be eligible for postretirement medical, dental,
vision and life insurance 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, hire date, and retirement date. Under the terms of
the Edison International Health and Welfare Plan ("PBOP Plan") each participating employer (Edison International or its
participating subsidiaries) is responsible for the costs and expenses of all PBOP benefits with respect to its employees and
former employees. A participating employer may terminate the PBOP benefits with respect to its employees and former
employees, as may SCE (as Plan sponsor), and, accordingly, the participants' PBOP benefits are not vested benefits.
The expected contributions (substantially all of which are expected to be made by SCE) for PBOP benefits are $33 million
for the year ended December 31, 2016. 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 established three voluntary employee beneficiary associations trusts ("VEBA Trusts") that can only be used to pay
for retiree health care benefits of SCE. Once funded into the VEBA Trusts, neither SCE nor Edison International can
subsequently terminate benefits and 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
78
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.
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
Special termination benefits
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:
Current liabilities
Long-term liabilities
Amounts recognized in accumulated other comprehensive loss
consist of:
Net loss
Amounts recognized as a regulatory (liability) asset:
Prior service credit
Net loss
Total not yet recognized as expense
Weighted-average assumptions used to determine obligations at
end of year:
Discount rate
Assumed health care cost trend rates:
Rate assumed for following year
Ultimate rate
Year ultimate rate reached
Edison International
SCE
Years ended December 31,
2015
2014
2015
2014
$
$
$
$
$
$
$
$
$
$
$
2,784
46
102
(2)
(500)
20
(100)
2,350
2,086
6
24
20
(100)
2,036
(314)
(15)
(299)
(314)
4
(9)
183
174
178
$
$
$
$
$
$
$
$
$
$
$
2,220
40
117
3
582
19
(197)
2,784
2,065
180
19
19
(197)
2,086
(698)
(15)
(683)
(698)
4
(19)
577
558
562
$
$
$
$
$
$
$
$
$
$
$
2,775
46
102
(2)
(500)
20
(100)
2,341
2,086
6
24
20
(100)
2,036
(305)
(15)
(290)
(305)
—
(9)
183
174
174
$
$
$
$
$
$
$
$
$
$
$
2,211
40
117
3
582
19
(197)
2,775
2,065
180
19
19
(197)
2,086
(689)
(15)
(674)
(689)
—
(19)
577
558
558
4.55%
4.16%
4.55%
4.16%
7.50%
5.00%
2022
7.75%
5.00%
2021
7.50%
5.00%
2022
7.75%
5.00%
2021
During 2015, the PBOP plan had actuarial gains of $500 million primarily related to $300 million in experience gains,
$140 million of income from an increase in the discount rate (from 4.16% at December 31, 2014 to 4.55% as of
December 31, 2015) due to higher interest rates, and the adoption of new mortality tables, as discussed below.
79
In 2015 and 2014, Edison International and SCE adopted new mortality tables that the Society of Actuaries released in
October each year that reflect changes in life expectancy. At December 31, 2015 and 2014, this adoption resulted in a change
in Edison International's PBOP plans' accumulated postretirement benefit obligation of $(62) million and $308 million,
respectively, including $(61) million and $307 million, respectively, for SCE.
PBOP expense components for continuing operations are:
(in millions)
Service cost
Interest cost
Expected return on plan assets
Special termination benefits1
Amortization of prior service credit
Amortization of net loss
Total expense
Edison International
SCE
Years ended December 31,
2015
2014
2013
2015
2014
2013
$
$
46
102
(116)
1
(12)
3
24
$
40
$
49
$
46
$
40
$
117
(108)
3
(36)
6
98
(114)
11
(36)
24
102
(116)
1
(12)
2
117
(108)
3
(35)
5
$
22
$
32
$
23
$
22
$
48
97
(114)
11
(35)
24
31
1 Due to the reduction in workforce, SCE has incurred costs for extended retiree health care coverage.
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. The estimated PBOP amounts that will be amortized to expense in 2016 for continuing operations
are as follows:
Unrecognized prior service credit to be amortized
Edison
International
SCE
$
(3)
$
(3)
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,
2015
2014
2013
4.16%
5.50%
7.75%
5.00%
2021
5.00%
5.50%
7.75%
5.00%
2020
4.25%
6.70%
8.50%
5.00%
2020
A one-percentage-point change in assumed health care cost trend rate would have the following effects on continuing
operations:
(in millions)
Edison International
SCE
One-
Percentage-
Point
Increase
One-
Percentage-
Point
Decrease
One-
Percentage-
Point
Increase
One-
Percentage-
Point
Decrease
Effect on accumulated benefit obligation as of December 31, 2015 $
Effect on annual aggregate service and interest costs
$
251
12
$
(206)
(9)
$
250
12
(205)
(9)
80
The following benefit payments are expected to be paid:
(in millions)
2016
2017
2018
2019
2020
2021 – 2025
Plan Assets
Edison
International
SCE
Years ended December 31,
$
$
101
106
111
115
119
649
101
106
110
114
118
646
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 2015
pension plan assets were 29% for U.S. equities, 17% for non-U.S. equities, 35% for fixed income, 15% for opportunistic and/
or alternative investments and 4% for other investments. Target allocations for 2015 PBOP plan assets (except for
Represented VEBA which is 85% for fixed income, 10% for opportunistic/private equities, and 5% global equities) are 41%
for U.S. equities, 17% for non-U.S. equities, 34% for fixed income, 7% for opportunistic and/or alternative investments, and
1% for other 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: Limited partnerships that invest in non-publicly traded entities.
• Other: Investments 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.
81
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 2% premium above public equity,
reflecting a premium for higher volatility and lower liquidity. For fixed income, the risk premium is based off of 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,
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. Common/collective funds are valued at
the net asset value ("NAV") of shares held. Although common/collective funds are determined by observable prices, they are
classified as Level 2 because they trade in markets that are less active and transparent. The fair value of the underlying
investments in equity mutual funds and equity common/collective funds are based upon stock-exchange prices. The fair value
of the underlying investments in fixed-income common/collective funds, 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. The partnerships classified as Level 2 can be readily redeemed at NAV and the underlying
investments are liquid, publicly traded fixed-income securities which have observable prices. The remaining partnerships/
joint ventures are classified as Level 3 because fair value is determined primarily based upon management estimates of future
cash flows. Other investment entities are valued similarly to common/collective funds and are therefore classified as Level 2.
The Level 1 registered investment companies are either mutual or money market funds. The remaining funds in this category
are readily redeemable at NAV and classified as Level 2 and are discussed further at footnote 7 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.
82
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, 2015 by asset class and level within the fair value hierarchy:
(in millions)
Level 1
Level 2
Level 3
Total
U.S. government and agency securities1
$
Corporate stocks2
Corporate bonds3
Common/collective funds4
Partnerships/joint ventures5
Other investment entities6
Registered investment companies7
Interest-bearing cash
Other
Total
Receivables and payables, net
Net plan assets available for benefits
SCE's share of net plan assets
Corporate stocks2
Corporate bonds3
Common/collective funds4
Partnerships/joint ventures5
Other investment entities6
Registered investment companies7
Interest-bearing cash
Other
Total
Receivables and payables, net
Net plan assets available for benefits
SCE's share of net plan assets
$
127
720
—
—
—
—
117
6
1
298
16
755
640
111
263
4
—
96
$
— $
—
—
—
214
—
—
—
—
425
736
755
640
325
263
121
6
97
$
971
$
2,183
$
214
$
$
$
3,368
(70)
3,298
3,080
$
140
716
—
—
—
—
113
10
5
329
14
801
524
110
278
30
—
100
$
— $
—
—
—
289
—
—
—
—
469
730
801
524
399
278
143
10
105
$
984
$
2,186
$
289
$
$
$
3,459
(5)
3,454
3,217
The following table sets forth the Master Trust investments that were accounted for at fair value as of December 31, 2014 by
asset class and level within the fair value hierarchy:
(in millions)
Level 1
Level 2
Level 3
Total
U.S. government and agency securities1
$
1 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.
2 Corporate stocks are diversified. For both 2015 and 2014, performance for actively managed separate accounts is primarily
benchmarked against the Russell Indexes (59%) and Morgan Stanley Capital International (MSCI) index (41%).
3 Corporate bonds are diversified. At December 31, 2015 and 2014, respectively, this category includes $123 million and
$102 million for collateralized mortgage obligations and other asset backed securities of which $25 million and $15 million are
below investment grade.
4 At December 31, 2015 and 2014, respectively, the common/collective assets were invested in equity index funds that seek to track
performance of the Standard and Poor's (S&P 500) Index (46% and 32%), Russell 1000 indexes (14% and 18%) and the MSCI
Europe, Australasia and Far East (EAFE) Index (16% and 20%). A non-index U.S. equity fund representing 22% and 27% of this
category for 2015 and 2014, respectively, is actively managed.
83
5 Partnerships/joint venture Level 2 investments consist primarily of a partnership which invests in publicly traded fixed income
securities. At December 31, 2015 and 2014, respectively, 22% and 55% of the Level 3 partnerships are invested in (1) asset backed
securities, including distressed mortgages and (2) commercial and residential loans and debt and equity of banks. At December 31,
2015 and 2014, respectively, 78% and 45% of the Level 3 partnerships are invested in private equity funds with investment
strategies that include branded consumer products, clean technology and California geographic focus companies.
6 Other investment entities were primarily invested in (1) emerging market equity securities, (2) a hedge fund that invests through
liquid instruments in a global diversified portfolio of equity, fixed income, interest rate, foreign currency and commodities
markets, and (3) domestic mortgage backed securities.
7 Level 1 of registered investment companies primarily consisted of a global equity mutual fund which seeks to outperform the
MSCI World Total Return Index. Level 2 primarily consisted of a short-term bond fund.
At December 31, 2015 and 2014, approximately 63% and 65%, respectively, of the publicly traded equity investments,
including equities in the common/collective funds, were located in the United States.
The following table sets forth a summary of changes in the fair value of Edison International's and SCE's Level 3
investments:
(in millions)
Fair value, net at beginning of period
Actual return on plan assets:
Relating to assets still held at end of period
Relating to assets sold during the period
Purchases
Dispositions
Transfers in and/or out of Level 3
Fair value, net at end of period
Postretirement Benefits Other than Pensions
2015
2014
$
289
$
390
47
(17)
38
(143)
—
$
214
$
114
(44)
13
(184)
—
289
The following table sets forth the VEBA Trust assets for SCE that were accounted for at fair value as of December 31, 2015
by asset class and level within the fair value hierarchy:
Level 1
Level 2
Level 3
Total
$
— $
(in millions)
Common/collective funds1
Corporate stocks2
Corporate notes and bonds3
Partnerships4
U.S. government and agency securities5
Registered investment companies6
Interest bearing cash
Other7
Total
Receivables and payables, net
Combined net plan assets available for benefits
—
—
73
—
—
—
—
73
424
222
867
93
242
63
31
118
$
$
2,060
(24)
2,036
$
— $
222
—
—
200
60
31
5
424
—
867
20
42
3
—
113
$
518
$
1,469
$
84
The following table sets forth the VEBA Trust assets for SCE that were accounted for at fair value as of December 31, 2014
by asset class and level within the fair value hierarchy:
(in millions)
Common/collective funds1
Corporate stocks2
Corporate notes and bonds3
Partnerships4
U.S. government and agency securities5
Registered investment companies6
Interest bearing cash
Other7
Total
Receivables and payables, net
Combined net plan assets available for benefits
Level 1
Level 2
Level 3
Total
$
— $
250
—
—
207
64
29
5
431
—
883
19
36
5
—
125
$
— $
—
—
105
—
—
—
—
431
250
883
124
243
69
29
130
$
555
$
1,499
$
105
$
$
2,159
(73)
2,086
1 At both December 31, 2015 and 2014, 38% of the common/collective assets are invested in a large cap index fund which seeks to track
performance of the Russell 1000 index. 41% of the assets in this category are in index funds which seek to track performance in the
MSCI All Country World Index Investable Market Index and MSCI Europe, Australasia and Far East (EAFE) Index. 17% in a non-
index U.S. equity fund which is actively managed.
2 Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (47%) and
the MSCI All Country World Index (53%) for both 2015 and 2014.
3 Corporate notes and bonds are diversified and include approximately $27 million and $31 million for commercial collateralized
mortgage obligations and other asset backed securities at December 31, 2015 and 2014, respectively.
4 At December 31, 2015 and 2014, respectively, 29% and 50% of the Level 3 partnerships category is invested in (1) asset backed
securities including distressed mortgages, (2) distressed companies and (3) commercial and residential loans and debt and equity of
banks. At December 31, 2015 and 2014, respectively, 71% and 50% of the Level 3 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.
5 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.
6 Level 1 registered investment companies consist of a money market fund.
7 Other includes $97 million and $111 million of municipal securities at December 31, 2015 and 2014, respectively.
At both December 31, 2015 and 2014, approximately 71% of the publicly traded equity investments, including equities in the
common/collective funds, were located in the United States.
The following table sets forth a summary of changes in the fair value of PBOP Level 3 investments:
(in millions)
Fair value, net at beginning of period
Actual return on plan assets
Relating to assets still held at end of period
Relating to assets sold during the period
Purchases
Dispositions
Transfers in and/or out of Level 3
Fair value, net at end of period
85
2015
2014
$
105
$
164
(6)
15
7
(47)
—
74
18
(1)
9
(85)
—
$
105
$
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 49.5 million shares, plus the
number of any shares subject to awards issued under Edison International's prior plans and outstanding as of April 26, 2007,
which expire, cancel or terminate without being exercised or shares being issued ("carry-over shares"). As of
December 31, 2015, Edison International had approximately 18 million shares remaining for future issuance under its
stock-based compensation plans.
The following table summarizes total expense and tax benefits (expense) associated with stock based compensation:
Edison International
2015
2014
2013
2015
Years ended December 31,
SCE
2014
2013
(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
compensation expense
$
$
Excess tax benefits2
$
14
$
7
7
1
29
12
15
$
$
16
16
7
1
40
16
15
$
15
$
4
7
1
27
11
5
$
$
$
$
$
$
$
8
4
4
—
16
7
23
$
$
$
8
8
4
—
20
8
20
11
2
4
—
17
7
2
1 Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income.
2 Reflected in "Settlements of stock-based compensation, net" in the financing section of Edison International's and SCE's consolidated
statements of cash flows and in "Common stock" in Edison International's consolidated balance sheets and "Additional paid-in capital"
in SCE's consolidated balance sheets.
Stock Options
Under various plans, Edison International has granted stock options at exercise prices equal to the closing price at the grant
date. Prior to 2007, average of the high and low price was used. 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, with expense recognized evenly over
the requisite service period, except for awards granted to retirement-eligible participants, as discussed in "Stock-Based
Compensation" in Note 1. Additionally, Edison International will substitute cash awards to the extent necessary to pay tax
withholding or any government levies.
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,
2015
5.9
1.6% – 2.1%
2.6% – 3.2%
2.6%
2014
6.0
1.8% – 2.1%
2.4% – 2.7%
2.7%
2013
6.2
1.0% – 2.1%
2.7% – 3.1%
2.8%
16.4% – 17.0%
17.8% – 19.1%
17.7% – 18.6%
16.5%
18.9%
17.7%
86
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 equals 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 2015. The volatility period used was 71 months, 72 months and 74 months at December 31, 2015, 2014 and 2013,
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, 2014
13,618,735
$
Granted
Expired
Forfeited
Exercised
Outstanding at December 31, 2015
Vested and expected to vest at December 31, 2015
Exercisable at December 31, 2015
SCE:
2,030,342
—
(171,107)
(2,611,373)
12,866,597
12,762,577
8,928,807
Outstanding at December 31, 2014
6,002,160
$
Granted
Expired
Forfeited
Exercised
Transfers, net
Outstanding at December 31, 2015
Vested and expected to vest at December 31, 2015
Exercisable at December 31, 2015
1,099,566
—
(109,719)
(1,085,438)
(66,512)
5,840,057
5,771,064
3,751,272
42.84
63.57
—
51.87
43.14
45.93
45.81
40.79
43.82
63.52
—
53.45
41.74
40.88
47.77
47.62
42.17
5.84
5.82
4.73
6.20
6.17
4.99
$
$
$
$
180
165
72
64
At December 31, 2015, total unrecognized compensation cost related to stock options and the weighted-average period the
cost is expected to be recognized are as follows:
(in millions)
Unrecognized compensation cost, net of expected forfeitures
Weighted-average period (in years)
Edison
International
SCE
$
$
13
2.3
9
2.4
87
Supplemental Data on Stock Options
Edison International
SCE
Years ended December 31,
(in millions, except per award amounts)
2015
2014
2013
2015
2014
2013
Stock options:
Weighted average grant date fair
value per option granted
$
Fair value of options vested
Cash used to purchase shares to
settle options
Cash from participants to exercise
stock options
Value of options exercised
Tax benefits from options
exercised
Performance Shares
$
7.54
20
170
113
57
23
$
7.26
17
300
205
95
39
5.40
17
199
140
59
24
$
7.53
$
7.34
$
11
69
45
24
10
9
181
125
56
23
5.38
10
130
92
38
15
A target number of contingent performance shares were awarded to executives in March 2015, 2014 and 2013 and vest at the
end of a three year period for each grant. The vesting of the grants is dependent upon market and financial performance
conditions 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). Performance shares awarded in 2014 and 2013 that are earned are settled half in cash and half in common stock,
while performance shares awarded in 2015 that are earned are settled solely in cash. The portion of performance shares that
can be settled in cash is classified as a share-based liability award. The fair value of these shares is remeasured at each
reporting period and the related compensation expense is adjusted. The portion of performance shares payable in common
stock is classified as a share-based equity award. Compensation expense related to these shares is based on the grant-date fair
value, which for each share is determined as the closing price of Edison International common stock on the grant date;
however, with respect to the portion of the performance shares payable in common stock that is subject to the financial
performance condition 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 of compensation expense. Performance shares expense is
recognized ratably over the requisite service period based on the fair values determined (subject to the adjustments discussed
above), except for awards granted to retirement-eligible participants.
The fair value of market condition performance shares is determined using a Monte Carlo simulation valuation model.
88
The following is a summary of the status of Edison International's nonvested performance shares:
Equity Awards
Liability Awards
Weighted-
Average
Grant Date
Fair Value
Shares
Weighted-
Average
Fair Value
Shares
Edison International:
Nonvested at December 31, 2014
128,300
$
55.66
127,975
$
92.92
Granted
Forfeited
Vested1
Nonvested at December 31, 2015
SCE:
—
(4,035)
(66,486)
57,779
—
55.93
50.85
61.18
109,154
(5,183)
(66,317)
165,629
68.44
Nonvested at December 31, 2014
71,797
$
56.06
71,520
$
92.33
Granted
Forfeited
Vested1
Affiliate transfers, net
Nonvested at December 31, 2015
—
(1,717)
(36,891)
(726)
32,463
—
56.89
50.82
54.81
62.01
59,213
(2,867)
(36,748)
(725)
90,393
68.64
1 Relates to performance shares that will be paid in 2016 as performance targets were met at December 31, 2015.
Restricted Stock Units
Restricted stock units were awarded to Edison International's and SCE's executives in March 2015, 2014 and 2013 and vest
and become payable on January 2, 2018, January 3, 2017 and December 31, 2015, 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.
The following is a summary of the status of Edison International's nonvested restricted stock units:
Edison International
SCE
Restricted
Stock Units
Weighted-
Average
Grant Date
Fair Value
Restricted
Stock Units
Weighted-
Average
Grant Date
Fair Value
Nonvested at December 31, 2014
433,319
$
Granted
Forfeited
Vested
Affiliate transfers, net
Nonvested at December 31, 2015
120,469
(10,210)
(295,435)
—
248,143
47.89
63.57
52.09
45.74
—
57.89
231,364
$
65,237
(5,108)
(155,046)
(2,072)
134,375
48.26
63.52
54.04
45.98
45.35
58.13
The fair value for each restricted stock unit awarded is determined as the closing price of Edison International common stock
on the grant date.
89
Workforce Reductions
SCE continues to focus on productivity improvements to mitigate rate pressure from its capital program, optimize its cost
structure and improve operational efficiency, which is expected to result in further workforce reductions through 2016.
During the year ended December 31, 2015, SCE increased the estimated impact for approved workforce reductions. The
following table provides a summary of changes in the accrued severance liability associated with these reductions:
(in millions)
Balance at January 1, 2015
Additions
Payments
Balance at December 31, 2015
$
$
35
26
(39)
22
The liability presented in the table above is reflected in "Other current liabilities" on the consolidated balance sheets. The
severance costs are included in "Operation and maintenance" on the consolidated statements of income.
Note 9.
Investments
Nuclear Decommissioning Trusts
Future decommissioning costs of removal of 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:
(in millions)
Stocks
Municipal bonds
U.S. government and agency securities
Longest
Maturity
Date
—
2054
2046
$
Corporate bonds
Short-term investments and receivables/payables1 One-year
Total
2057
Amortized Cost
Fair Value
December 31,
2015
2014
2015
2014
$
304
691
1,070
708
144
524
681
777
346
692
$
1,460
$
2,031
840
1,128
755
148
822
836
395
715
$
2,917
$
3,020
$
4,331
$
4,799
1 Short-term investments include $81 million and $164 million of repurchase agreements payable by financial institutions which earn
interest, are fully secured by U.S. Treasury securities and mature by January 5, 2016 and January 7, 2015 as of December 31, 2015 and
2014, respectively.
Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability.
Unrealized holding gains, net of losses, were $1.4 billion and $1.8 billion at December 31, 2015 and 2014, respectively.
90
The following table sets forth a summary of changes in the fair value of the trusts:
(in millions)
Years ended December 31,
2015
2014
2013
Balance at beginning of period
$
4,799
$
4,494
$
4,048
Gross realized gains
Gross realized losses
Unrealized (losses) gains
Other-than-temporary impairments
Interest, dividends and other
Contributions
Income taxes
Decommissioning disbursements
Administrative expenses and other
Balance at end of period
326
(26)
(364)
(29)
115
54
(64)
(471)
(9)
4,331
$
197
(5)
75
(14)
118
5
(62)
(4)
(5)
4,799
$
300
(32)
160
(47)
113
22
(66)
—
(4)
4,494
$
Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE. Deferred income taxes
related to unrealized gains at December 31, 2015 were $360 million. Accordingly, the fair value of Trust assets available to
pay future decommissioning costs, net of deferred income taxes, totaled $4.0 billion at December 31, 2015. Due to regulatory
mechanisms, changes in assets of the trusts from income items have no impact on operating revenue or earnings.
For the year ended December 31, 2015, the trust reimbursed SCE for $471 million of 2013, 2014 and 2015 Units 2 and 3
decommissioning costs. Under the San Onofre OII Settlement Agreement, recoveries from the nuclear decommissioning trusts
of 2013 and 2014 decommissioning costs were refunded to customers primarily through ERRA.
Acquisitions
On December 31, 2015, Edison Energy acquired three businesses for an aggregate purchase price of approximately
$100 million. Under the terms of the acquisition agreements, the sellers are entitled to additional consideration in the event
that certain financial thresholds are achieved. The maximum amount that could be earned under these agreements is
approximately $50 million over a four year period. The majority of the purchase price was allocated to goodwill and
identifiable intangibles ($90 million). Purchase price allocations are preliminary and subject to change.
Note 10. 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
7.90% in 2015 and 2014. The CPUC also 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.
91
Regulatory Assets
SCE's regulatory assets included on the consolidated balance sheets are:
(in millions)
Current:
Regulatory balancing accounts
Energy derivatives
Other
Total current
Long-term:
Deferred income taxes, net
Pensions and other postretirement benefits
Energy derivatives
Unamortized investments, net
San Onofre
Unamortized loss on reacquired debt
Regulatory balancing accounts
Environmental remediation
Other
Total long-term
Total regulatory assets
December 31,
2015
2014
$
1,088
$
382
159
19
560
3,757
849
1,027
182
1,043
201
36
129
288
7,512
8,072
$
$
159
7
1,254
3,405
1,218
850
255
1,288
201
44
107
244
7,612
8,866
SCE's regulatory assets related to energy derivatives are primarily an offset to unrealized losses on derivatives. The
regulatory asset changes based on fluctuations in the fair market value of the contracts, in which the original contracts expire
in 2 to 45 years.
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.
SCE's regulatory assets related to pensions and other post-retirement plans represent the unfunded net loss and prior service
costs of the plans (see "Pension Plans and Postretirement Benefits Other than Pensions" discussion in Note 8). This amount is
being recovered through rates charged to customers.
SCE's unamortized investments primarily include nuclear assets related to Palo Verde and legacy meters retired as part of the
Edison SmartConnect® program. Nuclear assets related to Palo Verde are expected to be recovered by 2047 and earned a
return of 7.90% in 2015 and 2014. SCE's unamortized investments related to legacy meters are expected to be recovered by
2017 and earned a rate of return of 6.46% in 2015 and 2014.
In accordance with the San Onofre OII Settlement Agreement, SCE is authorized to recover in rates its San Onofre regulatory
asset, generally over a ten-year period commencing February 1, 2012. Under the San Onofre OII Settlement Agreement (see
Note 11), SCE was allowed to earn a rate of return of 2.62% for the period 2014 – 2015 and is authorized to continue to earn
this rate as adjusted during the amortization period thereafter with changes in SCE's authorized return on debt and preferred
equity. SCE's regulatory assets related to San Onofre nuclear fuel will earn a return equal to commercial paper rate that the
CPUC uses to calculate interest on balancing accounts.
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 1 to 35 years.
SCE's regulatory assets related to environmental remediation represents a portion of the costs incurred at certain sites that
SCE is allowed to recover through customer rates. See "Environmental Remediation" discussed in Note 11.
92
Regulatory Liabilities
SCE's regulatory liabilities included on the consolidated balance sheets are:
(in millions)
Current:
December 31,
2015
2014
Regulatory balancing accounts
$
1,106
$
Other
Total current
Long-term:
Costs of removal
Recoveries in excess of ARO liabilities1
Regulatory balancing accounts
Other
Total long-term
Total regulatory liabilities
22
1,128
2,781
1,502
1,314
79
5,676
6,804
$
$
380
21
401
2,826
1,956
1,083
24
5,889
6,290
1 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 9).
SCE's regulatory liabilities related to costs of removal represent differences between asset removal costs recorded and
amounts collected in rates for those costs.
SCE's regulatory liability equal to nuclear decommissioning trust assets in excess of the related asset retirement obligations
which represent future refunds to customers if such assets are not used to decommission the related nuclear facilities. The
decrease in this regulatory liability resulted from SCE's obtaining access of decommissioning funds for Units 2 and 3 and
changes in market value for decommissioning trust funds for nuclear assets. For further information, see Note 1 and Note 9.
Net Regulatory Balancing Accounts
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.
Regulatory balancing 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 accounts do not have the right of offset and are
presented gross in the consolidated balance sheets. Under and over collections accrue interest based on a three-month
commercial paper rate published by the Federal Reserve.
93
The following table summarizes the significant components of regulatory balancing accounts included in the above tables of
regulatory assets and liabilities:
(in millions)
Asset (liability)
Energy resource recovery account
New system generation balancing account
Public purpose programs and energy efficiency programs
Base rate recovery balancing account
Tax accounting memorandum account and pole loading
Greenhouse gas auction revenue
FERC balancing accounts
Generator settlements
Other
Liability
December 31,
2015
2014
$
$
(439)
(171)
(683)
(319)
(248)
(75)
74
(4)
(137)
(2,002)
$
1,028
35
(874)
(5)
—
(182)
(32)
(197)
(104)
(331)
$
The 2015 GRC established a tax accounting memorandum account (referred to as "TAMA"), which provides that additional
2015 – 2017 tax benefits or costs associated with the following events be tracked: (1) tax accounting method changes, (2)
changes in tax laws and regulations impacting depreciation or tax repair deductions, (3) forecasted and actual differences in
tax repair deductions, and (4) the impact, if any, of a private letter ruling related to compliance with normalization regulations
of the IRS. As a result of this memorandum account, together with the balancing account for pole loading expenditures, any
differences between the forecasted tax repair deductions and actual tax repair deductions for 2015 – 2017 will be adjusted
annually through customer rates. The TAMA will also reflect the revenue requirement impact of the extension of bonus
depreciation.
SCE had participated in proceedings seeking recovery of refunds from certain sellers of electricity and natural gas during the
energy crisis in California in 2000 – 2001. SCE is authorized to refund to customers any refunds actually realized by SCE,
net of litigation costs and amounts retained by SCE as a shareholder incentive pursuant to an established sharing
arrangement. During 2014, the FERC approved generator settlement agreements which resulted in total refunds to customers
of $219 million of which $15 million is subject to a shareholder incentive.
Note 11. Commitments and Contingencies
Third-Party Power Purchase Agreements
SCE entered into various agreements, which were approved by the CPUC and met critical contract provisions (including
completion of major milestones for construction), to purchase power and electric capacity, including:
• Renewable Energy Contracts – California law requires retail sellers of electricity to comply with a RPS by delivering
renewable energy, primarily through power purchase contracts. Renewable energy contracts generally contain escalation
clauses requiring increases in payments. As of December 31, 2015, SCE had 93 renewable energy contracts which expire at
various dates through 2038.
• Qualifying Facility Power Purchase Agreements – Under the Public Utility Regulatory Policies Act of 1978 ("PURPA"),
electric utilities are required, with exceptions, to purchase energy and capacity from independent power producers that are
qualifying co-generation facilities and qualifying small power production facilities ("QFs"). As of December 31, 2015,
SCE had 71 QF contracts.
• Other Power Purchase Agreements – SCE has entered into agreements with third parties, including 6 combined heat and
power contracts, 9 tolling arrangements and 11 resource adequacy contracts which expire at various dates through 2025.
94
At December 31, 2015, the undiscounted future minimum expected payments for the SCE power purchase agreements that
have been approved by the CPUC and have completed major milestones for construction were as follows:
(in millions)
2016
2017
2018
2019
2020
Thereafter
Total future commitments
Renewable
Energy
Contracts
QF Power
Purchase
Agreements
Other
Purchase
Agreements
$
$
1,234
1,417
1,472
1,562
1,605
21,439
28,729
$
$
223
189
149
87
39
69
$
756
$
741
758
589
503
459
1,022
4,072
The table above includes contractual obligations for power procurement contracts that met the critical contract provisions as of
December 31, 2015. Additionally, as of December 31, 2015, SCE has signed contracts that have not met the critical contract
provisions that would increase contractual obligations by $29 million in 2016, $166 million in 2017, $257 million in 2018,
$352 million in 2019, $747 million in 2020 and $16.4 billion thereafter, if all principal provisions are completed.
Many of the power purchase agreements that SCE entered into with independent power producers are treated as operating and
capital leases. The following table shows the future minimum lease payments due under the contracts that are treated as
operating and capital leases (these amounts are also included in the table above). Due to the inherent uncertainty associated
with the reliability of the fuel source, expected purchases from most renewable energy contracts do not meet the definition of a
minimum lease payment and have been excluded from the operating and capital lease table below but remain in the table
above. The future minimum lease payments for capital leases are discounted to their present value in the table below using
SCE's incremental borrowing rate at the inception of the leases. The amount of this discount is shown in the table below as the
amount representing interest.
(in millions)
2016
2017
2018
2019
2020
Thereafter
Total future commitments
Amount representing executory costs
Amount representing interest
Net commitments
Operating
Leases
Capital
Leases
$
$
374
354
250
186
174
1,745
3,083
$
$
$
1
1
2
2
2
10
18
(7)
(3)
8
Operating lease expense for power purchase agreements was $1.7 billion in 2015, $1.7 billion in 2014 and $1.5 billion in
2013 (including contingent rents of $1.1 billion in 2015, $944 million in 2014 and $843 million in 2013). 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.
At December 31, 2015 and 2014, SCE's net capital leases reflected in utility plant on the consolidated balance sheets were
$8 million and $203 million, including accumulated amortization of $2 million and $46 million, respectively. SCE had
$1 million and $7 million included in "Other current liabilities" and $7 million and $196 million included in "Other deferred
credits and other long-term liabilities" at December 31, 2015 and 2014, respectively, representing the present value of the
minimum lease payments due under these contracts recorded on the consolidated balance sheets.
95
Other Lease Commitments
The following summarizes the estimated minimum future commitments for SCE's noncancelable other operating leases
(excluding SCE's power purchase agreements discussed above):
(in millions)
2016
2017
2018
2019
2020
Thereafter
Total future commitments
Operating
Leases –
Other
$
$
68
52
44
35
27
271
497
Operating lease expense for other leases (primarily related to vehicles, office space, nuclear fuel storage space and other
equipment) were $80 million in 2015, $96 million in 2014 and $78 million in 2013. Certain leases on office facilities contain
escalation clauses requiring annual increases in rent. The rentals payable under these leases may increase by a fixed amount
each year, a percentage over base year, or the customer price index.
Other Commitments
The following summarizes the estimated minimum future commitments for SCE's other commitments:
(in millions)
2016
2017
2018
2019
2020
Thereafter
Total
Other contractual obligations
$
181
$
140
$
101
$
56
$
59
$
547
$
1,084
Costs incurred for other commitments were $182 million in 2015, $90 million in 2014 and $153 million in 2013. SCE has fuel
supply contracts for Palo Verde which require payment only if the fuel is made available for purchase. SCE also has
commitments related to maintaining reliability and expanding SCE's transmission and distribution system.
The table above excludes other contractual obligations that have not met the critical contract provisions. As of December 31,
2015, SCE has signed capacity reduction contracts that have not met critical contract provisions and are, therefore, not
included in the table above. These contracts would increase the contractual obligations by $10 million in 2017, $98 million in
2018, $82 million in 2019, $79 million in 2020 and $483 million thereafter, if all principal provisions are completed.
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 provided indemnifications through contracts entered into in the normal course of business.
These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, and
indemnities for specified environmental liabilities and income taxes with respect to assets sold. 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.
SCE has indemnified the City of Redlands, California in connection with Mountainview's California Energy Commission
permit for cleanup or associated actions related to groundwater contaminated by perchlorate due to the disposal of filter cake
at the City's solid waste landfill. The obligations under this agreement are not limited to a specific time period or subject to a
maximum liability. SCE has not recorded a liability related to this indemnity.
96
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 these other proceedings will not, individually or in the
aggregate, materially affect its results of operations or liquidity.
San Onofre Related Matters
Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred
in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent
inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were
also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3.
Settlement of San Onofre CPUC Proceedings
In November 2014, the CPUC approved the San Onofre OII Settlement Agreement that SCE had entered into with TURN,
ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth. The San Onofre OII Settlement
Agreement resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the
related outages and subsequent shutdown of San Onofre. The San Onofre OII Settlement Agreement does not affect
proceedings related to recoveries from third parties described below, but does describe how shareholders and customers will
share any recoveries.
Challenges related to San Onofre CPUC Proceedings
A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the
CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and
December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case
appealed the dismissal to the Ninth Circuit in May 2015. Both the appeal and the application for rehearing remain pending.
In April 2015, the Alliance for Nuclear Responsibility ("A4NR") filed a petition to modify the CPUC's decision approving the
San Onofre OII Settlement Agreement based on SCE's alleged failures to disclose communications between SCE and CPUC
decision-makers pertaining to issues in the San Onofre OII. The petition seeks the reversal of the decision approving the San
Onofre OII Settlement Agreement and reopening of the OII proceeding. Subsequently, TURN and ORA filed responses
supporting A4NR's petition to reopen the San Onofre OII proceeding. In August 2015, ORA filed its own petition to modify
the CPUC's decision approving the San Onofre OII Settlement Agreement seeking to set aside the settlement and reopen the
San Onofre OII proceeding. SCE and SDG&E responded to this petition in September 2015. Both petitions remain pending
before the CPUC.
In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief
Executive Officer and Chief Financial Officer and was later amended to include SCE's former President as a defendant. The
lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte
contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than initially
reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International common stock
between March 21, 2014 and June 24, 2015.
Subsequently and also in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison
International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on
similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and
various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same
allegations was filed in August and was subsequently consolidated with the July 2015 federal derivative lawsuit.
In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison
International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the
federal derivative lawsuits discussed above.
97
In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief
Executive Officer and Treasurer by an Edison International employee, alleging claims under the Employee Retirement Income
Security Act ("ERISA"). The complaint purports to be filed on behalf of a class of Edison International employees who were
participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between March 27, 2014
and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew or should have
known that investment in the Edison International Stock Fund was imprudent because the price of Edison International
common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte
communications with CPUC decision-makers related to the San Onofre OII.
Edison International and SCE cannot predict the outcome of these proceedings.
Ex Parte Communications
In February 2015, SCE filed in the San Onofre OII proceeding a Late-Filed Notice of Ex Parte Communication regarding a
meeting in March 2013 between an SCE senior executive and the president of the CPUC, both of whom have since retired
from their respective positions. In August 2015, the OII Administrative Law Judge issued a ruling that nine additional
communications should have been reported in addition to a March 2013 communication that SCE had reported in February
2015. In December 2015, the CPUC issued a final decision that imposed a penalty of $16.74 million in connection with eight
communications that the decision finds should have been reported and two violations of a CPUC ethical rule (reflected in
"Operation and maintenance" on the consolidated statements of income).
NRC Proceedings
As part of the NRC's review of the San Onofre outage and proceedings related to the possible restart of Unit 2, the NRC
appointed an Augmented Inspection Team to review SCE's performance. In December 2013, the NRC finalized an Inspection
Report in connection with the Augmented Inspection Team's review and SCE's response to an earlier NRC Confirmatory
Action Letter. The NRC's report identified a "white" finding (low to moderate safety significance) for failing to ensure that
MHI's modeling and analysis were adequate. In November 2014, the NRC closed the "white" finding, confirming that there
were no additional issues identified that could impact SCE's ability to safely decommission San Onofre. The NRC also issued
an Inspection Report to MHI containing a Notice of Nonconformance for its flawed computer modeling in the design of San
Onofre's steam generators. On October 2, 2014, the NRC's Office of Inspector General ("OIG") published a report on the
NRC's oversight of SCE's evaluation process for the RSGs, which was used to determine whether changes in the design of a
component would require an amendment to the operating license of a nuclear power plant. The OIG determined that the NRC
"missed opportunities" in connection with its 2009 inspection of SCE's evaluation process, and concluded that without further
review of information concerning SCE's evaluation conclusions, there is no assurance that the NRC reached the correct
conclusion in its 2009 inspection that San Onofre did not need a license amendment for its steam generator replacement.
In July 2015, the NRC issued a final decision regarding SCE's compliance with the license amendment regulatory process
related to the RSGs, finding the issue to be moot, given the permanent cessation of operation of San Onofre. In March 2015,
the NRC issued a lessons learned report in which it restated earlier NRC inspection findings that SCE properly concluded that
the replacement steam generators at San Onofre did not require a formal license amendment prior to installation using a
common NRC process for replacement components.
Certain anti-nuclear groups and individual members of Congress have alleged that SCE knew of deficiencies in the steam
generators when they were installed or otherwise did not correctly follow NRC requirements for the design and installation of
the replacement steam generators, all of which SCE has vigorously denied, and have called for investigations, including by the
Department of Justice. SCE cannot predict when or whether ongoing proceedings by the NRC will be completed or whether
inquiries by other government agencies concerning how the RSG project was conducted will be initiated or reopened.
NEIL Insurance Claims
San Onofre carries accidental property damage and carried accidental outage insurance issued by Nuclear Electric Insurance
Limited ("NEIL"). Through August 30, 2014, the San Onofre owners had submitted approximately $433 million in claims
(SCE's share of which is approximately $339 million) under the accidental outage insurance. The accidental outage insurance
at San Onofre has been canceled prospectively as a result of the permanent retirement.
In October 2015, San Onofre owners reached an agreement with NEIL to resolve all insurance claims arising out of the
failures of the San Onofre replacement steam generators for a total payment by NEIL of $400 million (SCE's share of which is
approximately $313 million). According to the terms of the San Onofre OII Settlement Agreement, the settlement proceeds
will be applied to reimburse the costs of pursuing the recovery and then allocated 95% to customers and 5% to SCE
($20 million pre-tax). SCE customers' portion of amounts recovered from NEIL has been distributed to SCE customers via a
credit to SCE's ERRA account.
98
MHI Claims
SCE is also pursuing claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"), which designed and
supplied the RSGs. MHI warranted the RSGs for an initial period of 20 years from acceptance and is contractually obligated to
repair or replace defective items with dispatch and to pay specified damages for certain repairs. MHI's stated liability under
the purchase agreement is limited to $138 million and excludes consequential damages, defined to include "the cost of
replacement power;" however, limitations in the contract are subject to applicable exceptions both in the contract and under
law. SCE has advised MHI that it believes one or more of such exceptions apply and that MHI's liability is not limited to
$138 million. MHI has advised SCE that it disagrees. In October 2013, SCE sent MHI a formal request for binding arbitration
under the auspices of the International Chamber of Commerce in accordance with the purchase contract seeking damages for
all losses. In the request for arbitration, SCE alleges contract and tort claims and seeks at least $4 billion in damages on behalf
of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI has denied any liability and has asserted
counterclaims for $41 million, for which SCE has denied any liability. Each of the other San Onofre owners sued MHI,
alleging claims arising from MHI's supplying the faulty steam generators. These litigation claims have been stayed pending
the arbitration. The other co-owners (SDG&E and Riverside) have been added as additional claimants in the arbitration. The
arbitration is being conducted pursuant to a confidentiality order issued by the arbitration panel. Hearings are expected to
occur in the first half of 2016 and a decision may be issued by year-end 2016.
SCE, on behalf of itself and the other San Onofre co-owners, has submitted seven invoices to MHI totaling $149 million for
steam generator repair costs incurred through April 30, 2013. MHI paid the first invoice of $45 million, while reserving its
right to challenge it and subsequently rejected a portion of the first invoice and has not paid further invoices, claiming further
documentation is required, which SCE disputes. SCE recorded its share of the invoice paid (approximately $35 million) as a
reduction of repair and inspection costs in 2012.
Under the San Onofre OII Settlement Agreement, recoveries from MHI (including amounts paid by MHI under the first
invoice), if any, will first be applied to reimburse costs incurred in pursuing such recoveries, including litigation costs. To the
extent SCE's share of recoveries from MHI exceed such costs, they will be allocated 50% to customers and 50% to SCE.
The first $282 million of SCE's customers' portion of such recoveries from MHI will be distributed to customers via a credit to
a sub-account of SCE's Base Revenue Requirement Balancing Account ("BRRBA"), reducing revenue requirements from
customers. Amounts in excess of the first $282 million distributable to SCE customers will reduce SCE's regulatory asset
represented by the unamortized balance of investment in San Onofre base plant, reducing the revenue requirement needed to
amortize such investment. The amortization period, however, will be unaffected. Any additional amounts received after the
regulatory asset is recovered will be applied to the BRRBA.
The San Onofre OII Settlement Agreement provides the utilities with the discretion to resolve the NEIL and MHI disputes
without CPUC approval or review, but the utilities are obligated to use their best efforts to inform the CPUC of any settlement
or other resolution of these disputes to the extent this is possible without compromising any aspect of the resolution. SCE and
SDG&E have also agreed to allow the CPUC to review the documentation of any final resolution of the NEIL and MHI
disputes and the litigation costs incurred in pursuing claims against NEIL and MHI to ensure they are not exorbitant in relation
to the recovery obtained. There is no assurance that there will be any recovery from MHI or, if there is a recovery, that it will
equal or exceed the litigation costs incurred to pursue the recovery.
Long Beach Service Interruptions
In July 2015, SCE's customers who are served via the network portion of SCE's electric system in Long Beach, California
experienced service interruptions due to multiple underground vault fires and underground cable failures. No personal injuries
have been reported in connection with these events. SCE instituted an internal investigation and commissioned an external
investigation of these events and their causes, which revealed that the main cause of the interruptions was a lack of adequate
management oversight of the downtown network system. The investigations also revealed deficiencies in maintaining the
knowledge base on the configuration and operation of the system, and a lack of sophisticated controls needed to more
efficiently and effectively prevent and respond to the cascading events that occurred. These events and their causes are also
being investigated by the CPUC's SED. SCE is unable to estimate a possible loss or range of loss associated with any penalties
that may be imposed by the CPUC related to this matter. Subject to applicable deductibles, SCE is generally insured against
customer claims arising from these service interruptions.
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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, 2015, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites in which
the upper end of the range of the costs is at least $1 million) was $131 million, including $80 million related to San Onofre. In
addition to these sites, SCE also has 39 immaterial sites for which the total minimum recorded liability was $3 million. Of the
$134 million total environmental remediation liability for SCE, $129 million has been recorded as a regulatory asset. SCE
expects to recover $47 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) and $82 million through a mechanism that
allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several
sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the
extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no
reasonable estimate of cleanup costs can be made for these sites.
The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties
inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified
sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of
identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to
these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed
its recorded liability by up to $164 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.
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
five years are expected to range from $7 million to $26 million. Costs incurred for years ended December 31, 2015, 2014 and
2013 were $5 million, $4 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 $13.5 billion. SCE and other owners of San Onofre and
Palo Verde have purchased the maximum private primary insurance available ($375 million) through a Facility Form issued by
American Nuclear Insurers ("ANI"). 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 results in claims and/or costs which exceed the primary insurance
at that plant site, all 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
nuclear material at San Onofre, or while in transit to or from San Onofre. 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 NEIL property damage coverage for such events. Second, tort claims of onsite workers are
excluded, but SCE also maintains an ANI Master Worker Form policy that provides coverage for non-licensee workers. This
program provides a shared industry aggregate limit of $375 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.
100
Based on its ownership interests, SCE could be required to pay a maximum of approximately $255 million per nuclear
incident. However, it would have to pay no more than approximately $38 million per incident in any one year. 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.
NEIL, a mutual insurance company owned by entities with nuclear facilities, issues nuclear property damage and accidental
outage insurance policies. The amount of nuclear property insurance purchased for San Onofre and Palo Verde exceeds the
minimum federal requirement of $1.06 billion. These policies include coverage for decontamination liability. Property damage
insurance also covers damages caused by acts of terrorism up to specified limits. 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 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 $45 million per year. Insurance
premiums are charged to operating expense.
Wildfire Insurance
Severe wildfires in California have given rise to large damage claims against California utilities for fire-related losses alleged
to be the result of the failure of electric and other utility equipment. Invoking a California Court of Appeal decision, plaintiffs
pursuing these claims have relied on the doctrine of inverse condemnation, which can impose strict liability (including liability
for a claimant's attorneys' fees) for property damage. Prolonged drought conditions in California have also increased the risk
of severe wildfire events. On June 1, 2015, Edison International renewed its liability insurance coverage, which included
coverage for SCE's wildfire liabilities up to a $610 million limit (with a self-insured retention of $10 million per wildfire
occurrence). Various coverage limitations within the policies that make up this insurance coverage could result in additional
self-insured costs in the event of multiple wildfire occurrences during the policy period (June 1, 2015 to May 31, 2016). SCE
also has additional coverage for certain wildfire liabilities of $390 million, which applies when total covered wildfire claims
exceed $610 million, through June 14, 2016. SCE may experience coverage reductions and/or increased insurance costs in
future years. No assurance can be given that future losses will not exceed the limits of SCE's insurance coverage.
Spent Nuclear Fuel
Under federal law, the Department of Energy ("DOE") is responsible for the selection and construction of a facility for the
permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to
accept of 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. SCE, as operating agent, filed a lawsuit on behalf of the San
Onofre owners against the DOE in the Court of Federal Claims seeking damages of approximately $182 million for 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.
Additional legal action would be necessary to recover damages incurred after December 31, 2013. All damages recovered by
SCE are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset
fuel decommissioning or storage costs.
Note 12. 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. SCE's outstanding shares are not subject to mandatory redemption. There
are no dividends in arrears for the preferred or preference shares. Shares of SCE's preferred stock have liquidation and
dividend preferences over shares of SCE's common stock and preference stock. All cumulative preferred shares are
redeemable. When preferred shares are redeemed, the premiums paid, if any, are charged to common equity. No preferred
shares were issued or redeemed in the years ended December 31, 2015, 2014 and 2013. There is no sinking fund requirement
for redemptions or repurchases of preferred shares.
Shares of SCE's preference stock rank junior to all of the preferred stock and 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. There
is no sinking fund requirement for redemptions or repurchases of preference shares.
101
Preferred stock and preference stock is:
(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:
4.51% Series A (variable and noncumulative)
6.50% Series D (cumulative)
6.25% Series E (cumulative)
5.625% Series F (cumulative)
5.10% Series G (cumulative)
5.75% Series H (cumulative)
5.375% Series J (cumulative)
SCE's preferred and preference stock
Less issuance costs
Edison International's preferred and preference stock of utility
Shares
Outstanding
Redemption
Price
December 31,
2015
2014
650,000
$
1,200,000
1,653,429
1,296,769
$
25.50
25.80
28.75
25.80
3,250,000
1,250,000
350,000
190,004
160,004
110,004
130,004
100.00
100.00
1,000.00
2,500.00
2,500.00
2,500.00
2,500.00
$
16
30
41
33
—
125
350
475
400
275
325
16
30
41
33
325
125
350
475
400
275
—
2,070
(50)
2,020
$
2,070
(48)
2,022
$
Shares of Series D and E preference stock, issued in 2011 and 2012, respectively, may be redeemed at par, in whole or in part,
after March 1, 2016 and February 1, 2022, respectively. Shares of Series F, G, H and J preference stock, issued in 2012, 2013,
2014 and 2015, respectively, may be redeemed at par, in whole, but not in part, at any time prior to June 15, 2017,
March 15, 2018, March 15, 2024 and September 15, 2025, respectively, if certain changes in tax or investment company laws
occur. After June 15, 2017, March 15, 2018, March 15, 2024 and September 15, 2025, SCE may redeem the Series F, G, H
and J shares, respectively, at par, in whole or in part. For shares of Series H and J preference stock, distributions will accrue
and be payable at a floating rate from and including March 15, 2024 and September 15, 2025, respectively. Shares of
Series F, G, H and J preference stock were issued to SCE Trust I, SCE Trust II, SCE Trust III and SCE Trust IV, respectively,
special purpose entities formed to issue trust securities as discussed in Note 3. The proceeds from the sale of the shares of
Series J were used to redeem $325 million of the Company's Series A preference stock. Preference shares are not subject to
mandatory redemption.
At December 31, 2015, declared dividends related to SCE's preferred and preference stock were $14 million.
Note 13. Accumulated Other Comprehensive Loss
The changes in accumulated other comprehensive loss, net of tax, consist of:
(in millions)
Beginning balance
Pension and PBOP – net gain (loss):
Other comprehensive income (loss) before
reclassifications
Reclassified from accumulated other comprehensive loss1
Other
Change
Ending balance
Edison International
SCE
Years ended December 31,
2015
2014
2015
2014
$
(58) $
(13) $
(28) $
(11)
(8)
10
—
2
(56) $
(58)
11
2
(45)
(58) $
1
5
—
6
(22) $
(21)
2
2
(17)
(28)
$
1 These items are included in the computation of net periodic pension and PBOP expense. See Note 8 for additional information.
102
Note 14. Interest and Other Income and Other Expenses
Interest and other income and other expenses are as follows:
(in millions)
SCE interest and other income:
Equity allowance for funds used during construction
Increase in cash surrender value of life insurance policies and life insurance
benefits
Interest income
Other
Total SCE interest and other income
Other income of Edison International Parent and Other1
Total Edison International interest and other income
SCE other expenses:
Civic, political and related activities and donations
Other
Total SCE other expenses
Other expense of Edison International Parent and Other
Total Edison International other expenses
Years ended December 31,
2014
2013
2015
$
$
$
$
87
26
4
6
123
51
174
(35)
(24)
(59)
—
(59)
$
$
$
$
65
36
5
16
122
25
147
(35)
(44)
(79)
(1)
(80)
$
$
$
$
72
30
10
10
122
2
124
(37)
(37)
(74)
—
(74)
1 Reflects Edison Capital's income related to the sale of affordable housing projects.
Note 15. Discontinued Operations
EME Chapter 11 Bankruptcy
In December 2012, EME and certain of its wholly-owned subsidiaries filed voluntary petitions for relief under Chapter 11 of
the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of Illinois, Eastern Division. The Amended
Plan of Reorganization, including the EME Settlement Agreement, was completed on April 1, 2014 with the sale of
substantially all of EME's assets to NRG Energy, Inc. and the transactions called for in the EME Settlement Agreement,
including an initial cash payment to the Reorganization Trust (as defined below) of $225 million in April 2014.
In August 2014, Edison International entered into an amendment of the EME Settlement Agreement that finalized the
remaining matters related to the EME Settlement including setting the amount of the two installment payments. Edison
International made an installment payment of $204 million on September 30, 2015 and is scheduled to make the remaining
$214 million payment in September, 2016.
Income from discontinued operations, net of tax, was $35 million (pre-tax income of $15 million), $185 million (pre-tax loss
of $525 million) and $36 million for the years ended December 31, 2015, 2014 and 2013, respectively. The 2015 income was
primarily due to income tax benefits (from revised estimates based on filing of the 2014 tax returns) and insurance recoveries.
The 2014 income was related to the impact of completing the transactions called for in the EME Settlement Agreement and
income tax benefits from resolution of uncertain tax positions and other impacts related to EME. The pre-tax loss of
$525 million in 2014 was primarily related to the $225 million initial cash payment to the Reorganization Trust, the two
installment payments discussed above and the other assumed liabilities. The 2013 income was from income tax benefits of
$36 million from revised estimates of the tax impact of a tax deconsolidation of EME from Edison International as originally
contemplated prior to the EME Settlement. See Note 7 for more information.
103
Note 16. Supplemental Cash Flows Information
Supplemental cash flows information is:
Edison International
SCE
Years ended December 31,
(in millions)
2015
2014
2013
2015
2014
2013
Cash payments (receipts) for interest and taxes:
Interest, net of amounts capitalized
$
512
$
504
$
Tax payments (refunds), net
1
32
477
28
$
$
478
144
$
487
(88)
462
28
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock
Preferred and preference stock
Details of debt exchange:
$
156
$
136
$
14
18
Pollution-control bonds redeemed (2.875%)
Pollution-control bonds issued (1.875%)
Notes issued under EME Settlement Agreement
(203)
203
$ — $
—
—
418
116
30
—
$ — $
147
$ —
14
(203)
203
18
—
30
—
—
—
$ — $ — $ — $ —
—
SCE's accrued capital expenditures at December 31, 2015, 2014 and 2013 were $543 million, $837 million and $661 million,
respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash
flow in the period paid.
During 2015, an SCE power contract classified as a capital lease was amended, which resulted in a reduction in the lease
obligations and asset by $147 million.
Note 17. 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 such as payroll, employee benefit programs, all performed by Edison
International or SCE employees, 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 revenues, 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. At
December 31, 2015 and 2014, Edison International has recorded liabilities of $210 million and $184 million, respectively,
related to Capistrano Wind Holdings and Capistrano Wind for future payments due under the tax allocation agreements
assuming net operating losses and credits generated by these entities are monetized.
104
Note 18. Quarterly Financial Data (Unaudited)
Edison International's quarterly financial data is as follows:
(in millions, except per-share amounts)
Operating revenue
Operating income
Income (loss) from continuing operations1
Income (loss) from discontinued operations, net
Net income (loss) attributable to common
shareholders
Basic earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Diluted earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Dividends declared per share
Common stock prices:
High
Low
Close
$
$
$
$
$
Total
11,524
2,008
1,082
35
1,020
3.02
0.11
3.13
2.99
0.11
3.10
1.7325
69.59
55.18
59.21
Fourth
2015
Third
Second
First
$
$
$
$
$
2,341
340
(47)
(8)
(79)
(0.22)
(0.02)
(0.24)
(0.22)
(0.02)
(0.24)
0.4800
66.29
57.51
59.21
$
$
$
$
$
3,763
608
405
43
421
1.16
0.13
1.29
1.15
0.13
1.28
0.4175
63.18
55.52
63.07
$
$
$
$
$
2,908
524
406
—
379
1.16
—
1.16
1.15
—
1.15
0.4175
64.55
55.18
55.58
$
$
$
$
$
2,512
538
318
—
299
0.92
—
0.92
0.91
—
0.91
0.4175
69.59
61.02
62.47
1 In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets
previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions.
(in millions, except per-share amounts)
Operating revenue
Operating income
Income from continuing operations1
Income (loss) from discontinued operations, net
Net income attributable to common shareholders
Basic earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Diluted earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Dividends declared per share
Common stock prices:
High
Low
Close
Total
$ 13,413
2,472
1,536
185
1,612
$
$
$
$
4.38
0.57
4.95
4.33
0.56
4.89
1.4825
68.74
44.74
65.48
Fourth
2014
Third
Second
First
$
$
$
$
$
3,114
693
406
39
420
1.17
0.12
1.29
1.15
0.12
1.27
0.4175
68.74
55.88
65.48
$
$
$
$
$
4,356
874
524
(16)
480
1.52
(0.05)
1.47
1.51
(0.05)
1.46
0.3550
59.54
54.12
55.92
$
$
$
$
$
3,016
575
382
184
536
1.08
0.56
1.64
1.07
0.56
1.63
0.3550
58.24
53.63
58.11
$
$
$
$
$
2,926
331
224
(22)
176
0.61
(0.07)
0.54
0.61
(0.07)
0.54
0.3550
56.61
44.74
56.61
1 During the first quarter of 2014, SCE recorded an impairment charge of $231 million ($96 million after-tax) in 2014. During the fourth
quarter of 2014, SCE reduced its estimated impact of the San Onofre OII Settlement by $68 million ($24 million after-tax) consistent
with the advice for reimbursement of recorded costs.
105
SCE's quarterly financial data is as follows:
(in millions)
Operating revenue
Operating income
Net income (loss)1
Net income (loss) available for common stock
Common dividends declared
$
Total
11,485
2,080
1,111
998
611
$
Fourth
2,319
366
(51)
(80)
170
$
2015
Third
3,757
626
417
389
147
Second
First
$
2,901
536
412
384
147
$
2,508
550
333
305
147
1
In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets
previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions.
(in millions)
Operating revenue
Operating income
Net income1
Net income available for common stock
Common dividends declared
$
Total
13,380
2,529
1,565
1,453
525
$
Fourth
3,104
715
408
380
147
$
2014
Third
4,338
881
531
503
126
$
Second
First
3,014
593
392
362
126
$
2,924
342
234
208
126
1 During the first quarter of 2014, SCE recorded an impairment charge of $231 million ($96 million after-tax) in 2014. During the fourth
quarter of 2014, SCE reduced its estimated impact of the San Onofre OII Settlement by $68 million ($24 million after-tax) consistent
with the advice for reimbursement of recorded costs.
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. As a result of rounding, the total of the four quarters does not always equal the
amount for the year.
106
SELECTED FINANCIAL DATA
Selected Financial Data: 2011 – 2015
(in millions, except per-share amounts)
Edison International
Operating revenue
Operating expenses
Income from continuing operations
Income (loss) from discontinued operations,
net of tax
Net income (loss)
Net income (loss) attributable to common
shareholders
Weighted-average shares of common stock
outstanding (in millions)
Basic earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Diluted earnings (loss) per share:
Continuing operations
Discontinued operations
Total
Dividends declared per share
Total assets1, 2
Long-term debt excluding current portion
Capital lease obligations excluding current portion
Preferred and preference stock of utility
Common shareholders' equity
Southern California Edison Company
Operating revenue
Operating expenses
Net income
Net income available for common stock
Total assets2
Long-term debt excluding current portion
Capital lease obligations excluding current portion
Preferred and preference stock
Common shareholder's equity
Capital structure:
Common shareholder's equity
Preferred and preference stock
Long-term debt
2015
2014
2013
2012
2011
$ 11,524
9,516
1,082
$ 13,413
10,941
1,536
$ 12,581
10,866
979
$ 11,862
9,577
1,594
$ 10,588
8,527
1,100
35
1,117
1,020
326
3.02
0.11
3.13
$
$
185
1,721
1,612
326
4.38
0.57
4.95
$
$
36
1,015
915
326
2.70
0.11
2.81
$
$
(1,686)
(92)
(183)
326
(1,078)
22
(37)
326
$
$
4.61
(5.17)
(0.56)
$
$
3.20
(3.31)
(0.11)
$
$
2.99
0.11
3.10
1.7325
$ 50,310
10,964
49
2,020
11,368
$
$
4.33
0.56
4.89
1.4825
$ 49,734
10,234
196
2,022
10,960
$
$
2.67
0.11
2.78
1.3675
$ 46,225
9,825
203
1,753
9,938
$
$
4.55
(5.11)
(0.56)
1.3125
$ 44,394
9,231
210
1,759
9,432
$
$
3.17
(3.28)
(0.11)
1.285
$ 48,039
8,834
216
1,029
10,055
$ 11,485
9,405
1,111
998
$ 49,872
10,537
49
2,070
11,602
$ 13,380
10,851
1,565
1,453
$ 49,456
9,624
196
2,070
11,212
$ 12,562
10,811
1,000
900
$ 45,786
9,422
203
1,795
10,343
$ 11,851
9,572
1,660
1,569
$ 44,034
8,828
210
1,795
9,948
$ 10,577
8,454
1,144
1,085
$ 40,315
8,431
216
1,045
8,913
47.9%
8.6%
43.5%
49.0%
9.0%
42.0%
48.0%
8.3%
43.7%
48.4%
8.7%
42.9%
48.5%
5.7%
45.8%
1 Total assets includes assets from continuing and discontinued operations.
2 Effective December 31, 2015, Edison International and SCE adopted an accounting standard, retrospectively, that requires all deferred
income tax assets and liabilities be presented as noncurrent in the consolidated balance sheet. See "Notes to Consolidated Financial
Statements—Note 1. Summary of Significant Accounting Policies" for further information.
107
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 these 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, 2015, 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, 2015. Edison International's internal control over financial reporting as of December 31, 2015
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
Beginning in 2015, SCE commenced transitioning a portion of its information technology services to third-party providers
under managed services agreements. The transition of day-to-day responsibilities to outside service providers has resulted in
certain changes to business processes and internal controls over financial reporting. SCE continues to be responsible for the
design and operating effectiveness of controls over financial reporting and has taken steps to provide oversight of controls
performed by its managed service provider during this period of change and will continue to evaluate the operating
effectiveness of related controls during subsequent periods.
There were no other changes in Edison International's or SCE's internal control over financial reporting during the fourth
quarter of 2015 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.
108
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None.
BUSINESS
CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION
Edison International was incorporated in 1987 as the parent holding company of SCE, a California public utility. Edison
International also owns and holds interests in companies that are Competitive Businesses.
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. In 2015, SCE's total operating revenue of $11.5 billion was derived as follows: 43.3%
commercial customers, 37.8% residential customers, 5.3% industrial customers, 5.0% public authorities 2.1% agricultural
and other, and 6.5% other operating revenue.
Edison Energy Group – New Competitive Businesses
Edison International is developing its Competitive Businesses as it continues to see merit in the ownership and operation of
initially small, targeted investments in energy services that utilize technologies and markets to capitalize on changes in the
electricity industry as a matter of corporate strategy. The Competitive Businesses are held by the Edison Energy Group.
The principal activities during 2015 and 2014 were behind the meter sales of solar-generated power to commercial and
industrial customers under power purchase agreements or the sale of distributed generation systems directly to the customer
(build/transfer contracts) through a subsidiary of Edison Energy Group, SoCore Energy LLC. As of December 31, 2015,
SoCore Energy had constructed and achieved commercial operations for 54 MW of rooftop solar systems in 16 states.
Edison Energy, LLC plans to broaden its products and services offered to commercial and industrial customers to include
various energy advisory services and products that help simplify and optimize the customers' evolving energy needs amid
uncertainty around changing technologies and regulation. This may include the acquisition of companies specializing in one
or more of these services as well as internally-developed products and services. On December 31, 2015, Edison Energy
acquired three businesses for an aggregate purchase price of approximately $100 million. For more information, see "Notes
to Consolidated Financial Statements—Note 9. Investments." These acquisitions expanded Edison Energy’s capability to
provide engineering design and construction services, energy procurement advisory services, including utility bill processing
and analytics, and the capability to structure transactions to source long-term renewable resources directly to large
commercial or industrial customers.
Edison Transmission, LLC’s focus is on solicitations for competitive transmission projects outside SCE's territory, where it
works alone or with other transmission companies to develop and bid on projects and, if successful, make investment in such
competitive transmission projects that bear a FERC authorized rate of return. In addition, Edison Transmission is one of the
eight founders of Grid AssuranceTM, a limited liability company developing grid resiliency offerings for domestic utilities.
Edison Water Resources, LLC is focused on developing reliable, sustainable and local sources of new water through a variety
of water purification and treatment technologies. Edison Water Resources seeks to support state and local goals related to the
drought in California and will focus initially on the use of onsite wastewater recycling units and small, energy-efficient,
reverse osmosis units to purify brackish groundwater.
109
To date, these investments are below 1% of the total consolidated assets and, therefore, not material to be reported as a
business segment.
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 shall 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 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
affiliate and (2) causing or abetting a utility's violation of the rules, including providing preferential treatment to affiliates.
Employees and Labor Relations
At December 31, 2015, Edison International and its consolidated subsidiaries had an aggregate of 12,768 full-time
employees, 12,678 of which were full-time employees at SCE.
Approximately 3,880 of SCE's full-time employees are covered by collective bargaining agreements with the International
Brotherhood of Electrical Workers ("IBEW"). The IBEW collective bargaining agreements expire on December 31, 2017.
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 solar
rooftop construction. For further information on nuclear and wildfire insurance, see "Notes to Consolidated Financial
Statements—Note 11. Commitments and Contingencies—Contingencies."
SOUTHERN CALIFORNIA EDISON COMPANY
Regulation
CPUC
The CPUC has the authority to regulate, among other things, retail rates, 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.
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.
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 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.
110
SCE has a formal cyber security program that covers SCE's information technology systems as well as 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. The program is also engaged in the protection of SCE's customer
information.
Nuclear Power Plant Regulation
The NRC has jurisdiction with respect to the safety of the 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 "Management Overview—Permanent Retirement of San Onofre and San Onofre OII Settlement" in the
MD&A.
Other Regulatory Agencies
The construction, planning and project site identification of SCE's transmission lines and substation facilities require the
approval of many governmental agencies and compliance with various laws in addition to the CPUC and FERC. These
include various state regulatory agencies depending on the project location; the CAISO, 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; and regional water quality control boards. 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.
Overview of Ratemaking Process
CPUC
Revenue authorized by the CPUC through triennial 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. 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 two years are set by a methodology established in the
GRC proceeding, which generally, among other items, includes annual allowances for escalation in operation and
maintenance costs and additional changes in capital-related investments. In December 2014, the CPUC adopted a new risk
assessment protocol, which includes a triennial safety model assessment proceeding ("S-MAP") to evaluate the utility models
used to prioritize safety risks, examine the utilities' assessment of their key risks and their proposed mitigation programs, and
provide annual reporting of risk spending and mitigation results.
SCE's 2015 GRC authorized revenue requirements for 2015, 2016, and 2017 of $5.182 billion, $5.391 billion, and
$5.663 billion, respectively. For further discussion of the 2015 GRC, see "Management Overview—Regulatory Proceedings
—2015 General Rate Case" in the MD&A.
The CPUC regulates SCE's cost of capital, including its capital structure and authorized rates of return. SCE's authorized
capital structure is 43% long-term debt, 9% preferred equity and 48% common equity. SCE's currently authorized cost of
capital consists of: cost of long-term debt of 5.49%, cost of preferred equity of 5.79% and return on common equity of
10.45%. In November 2015, the CPUC granted a request made by SCE and the other Investor-owned utilities to postpone the
filing of new cost of capital applications from April 2016 to April 2017, thus extending the current cost of capital mechanism
through 2017. For more information, see "Management Overview—Regulatory Proceedings—Cost of Capital" in the
MD&A. The mechanism provides for an automatic adjustment to SCE's authorized cost of capital if the utility bond index
changes beyond certain thresholds on an annual basis. The return on common equity will remain at 10.45% in 2016 and
through 2017 subject to CPUC approval.
SCE's return on investment is established by multiplying an authorized rate of return, determined in separate cost of capital
proceedings, by SCE's authorized CPUC rate base.
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 risk related to retail electricity sales.
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Balancing accounts (also referred to as cost-recovery mechanisms) are typically 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's balancing account for fuel and power procurement-related costs is referred to as the ERRA balancing account. 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 balancing account that allows for a rate adjustment if the balancing
account over- or under-collection exceeds 5% of SCE's prior year's revenue that is classified as generation for retail rates. For
2016, the trigger amount is approximately $326 million. At December 31, 2015, SCE's overcollection in the ERRA balancing
account was approximately $420 million, which is being refunded to customers in rates beginning on January 1, 2016.
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. If SCE is found to
be unreasonable or imprudent with respect to its utility-owned generation outages and contract administration activities, then
this could negatively impact SCE's earnings and cash flows.
FERC
Revenue authorized by the FERC is intended to provide SCE with recovery of its prudently-incurred transmission costs,
including a return on its net investment in transmission assets (also referred to as "rate base"). In November 2013, the FERC
approved SCE's settlement to implement a formula rate effective January 1, 2012 to determine SCE's FERC transmission
revenue requirement, including its construction work in progress ("CWIP") revenue requirement that was previously
recovered through a separate mechanism. Under operation of the formula rate, transmission revenue will be updated to actual
cost of service annually. The transmission revenue requirement and rates are updated each December, to reflect a forecast of
costs for the upcoming rate period, as well as a true up of the transmission revenue to actual costs incurred by SCE in the
prior calendar year on its formula rate. The FERC weighted average ROE, including project and other incentives, is
comparable to the CPUC ROE of 10.45% and can vary based on the mix of project costs that have different incentives. The
moratorium, provided for in the settlement, on modifications to the formula rate tariff including the FERC ROE, ended on
June 30, 2015. For further information on the current FERC formula rates, related transmission revenue requirements and rate
changes, see "Management Overview—Regulatory Proceedings—FERC Formula Rates" 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 four-tier residential rate structure. Each tier represents a certain electricity usage level and within each increasing
usage level, the electricity is priced at a higher rate per kilowatt hour. Although, for more than a decade after the energy
crisis, statutory restrictions on increasing Tier 1 and 2 rates resulted in shifting much of the cost of residential rate increases
to the higher tier/usage customers, the California legislature passed a law ("AB 327") in October 2013 that lifted the
restrictions on Tier 1 and 2 rates. The CPUC subsequently approved increases to Tier 1 and 2 rates that went into effect in
July 2014. In July 2015, the CPUC adopted an approach for flattening the tiered rate structure over time so that, by 2019,
SCE will have only two tiers with a price differential of 25% and a separate Super User Electric Surcharge for customers
consuming more than 400% of average usage. The CPUC also approved a $10 per month minimum bill ($5 for low-income
customers), which went into effect in July 2015. The increased minimum bill permits SCE to recover a larger portion of its
fixed costs of serving no- or low-usage residential customers through a minimum charge rather than through energy charges
that vary with usage. For information on rates for customers with renewable generation systems, see "—Competition" below.
Energy Efficiency Incentive Mechanism
In December 2012, the CPUC adopted an energy efficiency incentive mechanism for the 2010 – 2012 energy efficiency
program performance period. The mechanism used an incentive calculation that is based on actual energy efficiency
expenditures. In September 2013, the CPUC adopted a new energy efficiency incentive mechanism called the Energy Savings
and Performance Incentive Mechanism ("ESPI"). The ESPI applies starting with the 2013 – 2014 energy efficiency program
cycle and continue for subsequent cycles, until further notice. The ESPI is comprised of performance/savings rewards and
management fees based on actual energy efficiency expenditures and does not contain any provisions for penalties. The
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proposed ESPI schedule for earning claims anticipates payments of the incentive rewards occurring between one and two
years after the relevant program year. For further information on the energy efficiency awards, see "Management Overview—
Regulatory Proceedings—Energy Efficiency Incentive Mechanism" in the MD&A.
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. Less than 20% of the needed power is 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 are designed to operate in response to changes in demand
for power. The physical natural gas purchased by SCE is sourced in competitive interstate markets. SoCalGas provides the in-
state pipeline transportation service to the gas-fueled generation stations that SCE controls. SoCalGas is experiencing a
significant natural gas fuel leak at its Aliso Canyon underground gas storage facility. If the storage facility is not returned to
service, SCE anticipates that increased gas-use restrictions would increase the cost of electricity for customers and potentially
impact grid reliability. However, the price increase would not affect SCE's earnings because decoupled costs of fuel and
purchased-power are recovered from customers through balancing accounts. 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.
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 generation and purchases for its load requirements.
Competition
SCE faces retail competition in the sale of electricity to the extent that federal and California laws permit other entities to
provide electricity and related services to customers within SCE's service area. While California law provides only limited
opportunities for customers in SCE's service area to choose to purchase power directly from an energy service provider other
than SCE, a limited, phased-in expansion of customer choice (direct access) for nonresidential customers was permitted
beginning in 2009. SCE also faces competition from cities and municipal districts that create municipal utilities or
community choice aggregators. Competition between SCE and other electricity providers is conducted mainly on the basis of
price.
SCE also faces increased competition from customer-owned power generation alternatives, such as roof-top solar facilities,
becoming available to its customers as a result of technological developments, federal and state subsidies, and declining costs
of such alternatives.
Legislation passed in 1995 encouraged private residential and commercial investment in renewable energy resources by
requiring SCE to offer a net energy metering ("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 twelve 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 non-bypassable, standby and departing load charges and interconnection fees.
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In January 2016, the CPUC issued a decision implementing 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 will also continue to be exempted from standby and departing load charges, but will be
required to pay a $75 interconnection fee and to select a Time-of-Use ("TOU") retail rate. The CPUC will consider making
additional adjustments to the NEM tariff when it adopts default TOU rates in 2019.
The effect of these types of competition on SCE generally is to reduce the amount of electricity purchased by customers.
However customers, except for NEM customers, who use alternative electricity providers, typically continue to utilize and
pay for SCE's transmission and distribution services. 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. The FERC has made changes to its transmission planning requirements with the goal of opening transmission
development to competition from independent developers. The FERC adopted 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. In compliance with these rules, regional entities,
such as independent system operators, have created 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. In December 2014, the FERC issued orders approving the CAISO's process for regional planning and
competitive solicitations and the CAISO's interregional planning process. The CAISO has held competitive solicitations
pursuant to the new rules and independent service providers have been selected.
Properties
SCE supplies electricity to its customers through extensive transmission and distribution networks. Its transmission facilities,
which include sub-transmission facilities and are located primarily in California but also in Nevada and Arizona, deliver
power from generating sources to the distribution network and consist of lines ranging from 33 kV to 500 kV and substations.
SCE's distribution system, which takes power from substations to customers, includes over 53,000 line miles of overhead
lines, 38,000 line miles of underground lines and approximately 800 distribution substations, all of which are located in
California. SCE owns the generating facilities listed in the following table:
Generating Facility
Hydroelectric Plants (33)
Pebbly Beach Generating Station
Mountainview Units 3 and 4
Peaker Plants (5)
Location
(in CA, unless
otherwise noted)
Various
Catalina Island
Redlands
Various
Fuel Type
Hydroelectric
Diesel
Natural Gas
Natural Gas
Palo Verde Nuclear Generating
Phoenix, AZ
Nuclear
Station
Solar PV Plants (25)
Total
Various
Photovoltaic
SCE's
Ownership
Interest
(%)
Net
Physical
Capacity
(in MW)
100% 1,153
100%
9
100% 1,050
245
100%
15.8% 3,739
100%
91
6,287
SCE's
Capacity
pro rata share
(in MW)
1,153
9
1,050
245
591
91
3,139
Operator
SCE
SCE
SCE
SCE
APS
SCE
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.
The majority of SCE's hydroelectric plants and related reservoirs 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. SCE continuously monitors and maintains these licenses. 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
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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. 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.
ENVIRONMENTAL REGULATION OF EDISON INTERNATIONAL AND SUBSIDIARIES
Legislative and regulatory activities by federal, state, and local authorities in the United States relating to energy and the
environment impose numerous restrictions on the operation of existing facilities and affect the timing, cost, location, design,
construction, and operation of new facilities by Edison International's subsidiaries, as well as the cost of mitigating the
environmental impacts of past operations. The environmental regulations and other developments discussed below may
impact SCE's natural gas and diesel power plants and natural gas power plants owned by others that SCE purchases power
from, and accordingly, the discussion in this section focuses mainly on regulations applicable to California. For more
information on environmental risks, see "Risk Factors—Risks Relating to Southern California Edison Company—
Environmental Risks."
Edison International and SCE continue to monitor legislative and regulatory developments and to evaluate possible strategies
for compliance with environmental regulations. Additional information about environmental matters affecting Edison
International and its subsidiaries, is included in "Notes to Consolidated Financial Statements—Note 11. Commitments and
Contingencies—Contingencies—Environmental Remediation."
Air Quality
The CAA, which regulates air pollutants from mobile and stationary sources, has a significant impact on the operation of
fossil fuel plants. The CAA requires the US EPA to establish concentration levels in the ambient air for six criteria pollutants
to protect public health and welfare. These concentration levels are known as NAAQS. The six criteria pollutants are carbon
monoxide, lead, nitrogen dioxide, ozone, particulate matter, and SO2.
Federal environmental regulations of these criteria pollutants require states to adopt state implementation plans, known as
SIPs, for certain pollutants, which detail how the state will attain the standards that are mandated by the relevant law or
regulation. The SIPs must be equal to or more stringent than the federal requirements and must be submitted to the US EPA
for approval. Each state identifies the areas within its boundaries that meet the NAAQS (attainment areas) and those that do
not (non-attainment areas), and must develop a SIP both to bring non-attainment areas into compliance with the NAAQS and
to maintain good air quality in attainment areas. Much of southern California is in a non-attainment area for several criteria
pollutants.
National Ambient Air Quality Standards
The US EPA has proposed primary and secondary NAAQS for 8-hour ozone. Areas in SCE's service area were classified in
various degrees of nonattainment with these standards. California has developed air quality management plans and updated
its SIP to outline how compliance with the NAAQS will be achieved, but these plans remain subject to US EPA approval and
challenges from environmental groups in federal court. The implementation plans and proposed revisions call for more
stringent restrictions on air emissions, which could further increase the difficulty of siting new natural gas fired generation in
Southern California.
Water Quality
Clean Water Act
Regulations under the federal Clean Water Act dictate permitting and mitigation requirements for many of SCE's construction
projects, and govern critical parameters at generating facilities, such as the temperature of effluent discharges and the
location, design, and construction of cooling water intake structures at generating facilities. Federal standards intended to
protect aquatic organisms by reducing capture in the screens attached to cooling water intake structures (impingement) at
generating facilities and the water volume brought into the facilities (entrainment) have been finalized. However, due to the
decision to permanently retire San Onofre Units 2 and 3, SCE sought relief in order to avoid material capital expenditures at
San Onofre.
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California Restriction on the Use of Ocean-Based Once-Through Cooling
California has a US EPA-approved program to issue permits for the regulation of Clean Water Act discharges. California also
regulates certain discharges not regulated by the US EPA. In 2010, the California State Water Resources Control Board
("SWRCB") issued a policy, which established significant restrictions on the use of ocean water by existing once-through
cooled power plants along the California coast. The policy required an independent engineering study to be completed
regarding the feasibility of compliance by California's two coastal nuclear power plants. In January 2015, the SWRCB
notified SCE that due to the reduced intake flow of water at San Onofre during decommissioning, SCE would not be required
to complete the independent engineering study. The SWRCB also informed SCE that for as long as any intake of ocean water
continues at San Onofre, a large organism exclusion device would have to be installed on the offshore intakes no later than
December 31, 2016 to prevent the inadvertent taking of large marine organisms.
The policy's implementation schedule requires once-through cooled, gas-fired coastal generation facilities that provide power
to SCE to phase out the use of once-through cooling by 2020. SCE is engaged in procuring new sources of electricity to
replace suppliers that shut down due to these requirements.
Greenhouse Gas Regulation
There have been a number of federal and state legislative and regulatory initiatives to reduce GHG emissions. Any climate
change regulation or other legal obligation that would require substantial reductions in GHG emissions or that would impose
additional costs or charges for the emission of GHGs could significantly increase the cost of generating electricity from fossil
fuels, as well as the cost of purchased power.
Federal Legislative/Regulatory Developments
In August 2015, the US EPA issued final rules governing GHG emission standards for existing fossil-fuel power
plants. Known as the Clean Power Plan, the rules establish state-specific goals and guidelines for the reduction of GHG
emissions from existing sources, including heat rate efficiency improvements at coal plants, displacement of coal-fired
electric generation with increased utilization of natural gas combined cycle unit generation, and expanding deployment of
renewable resources. The Clean Power Plan requires states to impose standards of performance limits for existing fossil fuel-
fired electric generating units, or equivalent statewide intensity-based or mass-based CO2 binding goals or limits. States are
required either to submit state plans to the US EPA by the Fall of 2016 identifying how they will comply with the rules, or to
submit interim plans, along with a request for a two-year extension. Final plans for all states are due by the Fall of 2018. SCE
is participating in the stakeholder efforts to develop the California state plan. Both the timing and the substance of the Clean
Power Plan are subject to ongoing judicial challenges and on February 9, 2016, the US Supreme Court blocked the
implementation of the Clean Power Plan pending the completion of the judicial challenges. This action is expected to delay
the imposition of the deadlines for the state plans discussed above. Until the state plans are developed and approved by the
US EPA, SCE cannot predict the potential compliance costs and market risks associated with the Clean Power Plan.
Regulation of GHG emissions pursuant to the Clean Power Plan could affect efforts to modify SCE's facilities in the future,
and could subject new capital projects to additional permitting or emissions control requirements that could delay such
projects.
Since 2010, the US EPA's Final Mandatory GHG Reporting Rule has required all sources within specified categories,
including electric generation facilities, to monitor emissions, and to submit annual reports to the US EPA by March 31 of
each year. SCE's 2015 GHG emissions from utility-owned generation are estimated to be approximately 2.4 million metric
tons.
Regional Initiatives and State Legislation
Regional initiatives and state legislation also require reductions of GHG emissions and to the extent those requirements are
more stringent than federal requirements, utilities and generators will likely be required to satisfy the regional and state
requirements in addition to the federal standards.
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SCE's operations in California are subject to two laws governing GHG emissions. The first law, the California Global
Warming Solutions Act of 2006 (also referred to as AB 32), establishes a comprehensive program to reduce GHG emissions.
AB 32 required the California Air Resources Board ("CARB") to develop regulations that would reduce California's GHG
emissions to 1990 levels by 2020. The CARB regulations became effective in 2012 and established a California cap-and-
trade program. 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. GHG emitters can also meet up to 8% of their
AB 32 cap-and-trade obligations by participating in verified offset programs, such as reforestation, that have recognized
effects on reducing atmospheric GHGs.
The second law, SB 1368, required the CPUC and the California Energy Commission to adopt GHG emission performance
standards that apply to California investor-owned and publicly owned utilities' long-term arrangements for the purchase of
electricity. The standards that have been adopted prohibit these entities, including SCE, from entering into long-term financial
commitments with generators that emit more than 1,100 pounds of CO2 per MWh, which is the performance of a combined-
cycle natural gas turbine generator.
In 2011, California enacted a law to require California retail sellers of electricity to deliver 33% of their customers' electricity
requirements from renewable resources, as defined in the statute. The CPUC set delivery quantity requirements applicable to
SCE that incrementally increase to 33% over several periods between January 2011 and December 2020. In October 2015,
California enacted SB 350, which increases the amount of electricity from renewable resources that California retail sellers
must deliver after 2020 to 40% of retail sales by December 2024, 45% of retail sales by December 2027, and 50% of retail
sales by December 2030.
SCE's delivery of eligible renewable resources to customers was approximately 21% of its total energy portfolio for the
compliance period 2011 - 2013, which met SCE's goal for that period. SCE expects to meet its compliance goal for the
2014 – 2016 compliance period.
Litigation Developments
Litigation alleging that GHGs have caused damages for which plaintiffs seek recovery may affect SCE, whether or not it is
named as a defendant. The legal developments in this area have focused on whether lawsuits seeking recovery for such
alleged damages present questions capable of judicial resolution or political questions that should be resolved by the
legislative or executive branches.
In 2011, the U.S. Supreme Court dismissed public nuisance claims against five power companies related to GHG emissions.
In the dismissal, the Supreme Court ruled that the CAA, and the US EPA actions it authorizes, displace federal common law
nuisance claims that might arise from the emission of GHGs. The Supreme Court also affirmed that at least some of the
plaintiffs had standing to bring the case, but did not determine whether the CAA also preempts state law claims that might
arise from the same circumstances.
Other suits alleging causes of action that include negligence, public and private nuisance, trespass, and violation of the public
trust have been dismissed by several courts on threshold grounds including whether the cases present questions that can be
resolved by the courts and whether the plaintiffs have the right to bring the cases. However, various groups of plaintiffs
continue to explore and assert legal theories under which they seek to obtain recovery for past alleged harm, or have courts
issue rulings that will control levels of current and future GHG emissions. Thus, the defendants in the dismissed actions,
including SCE and other Edison International subsidiaries, together with other industrial companies associated with GHG
emissions, may be required to defend such actions in both state and federal courts for the foreseeable future.
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—Southern California Edison Company—
Properties."
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LEGAL PROCEEDINGS
Shaver Lake Dam Liner Permit Violation Proceeding
In 2011, SCE installed a PVC plastic geomembrane liner on the Shaver Lake Dam to prevent water seepage. Before starting
the project, SCE received the required regulatory permits and approvals. SCE and the California Department of Fish and
Wildlife executed a Streambed Alteration Agreement in November 2011 that governed SCE’s activities in Shaver Lake as
required by state and federal law. SCE also obtained the required federal Clean Water Act Certification in November 2011 for
the project’s completion.
In February 2012, the California Department of Fish and Wildlife and the Central Valley Regional Water Quality control
Board issued letters alleging that SCE had violated provisions of the Streambed Alteration Agreement and certain conditions
of the federal Clean Water Act Certification, respectively. Both letters alleged that during the draining of Shaver Lake, SCE
failed to prevent the discharge of sediment into an adjoining creek, causing the deaths of fish in the lake and creek. In
October 2014, SCE received a pre-issuance draft of an Administrative Civil Liability Complaint from the Central Valley
Regional Water Quality Control Board alleging violations of certain permit conditions relating to the Shaver Lake Dam
Project. The Regional Water Quality Control Board is seeking $25 million in civil penalties for the violations. SCE disputes
the allegations but is working with the regulatory agencies to resolve the matter.
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EXECUTIVE OFFICERS OF EDISON INTERNATIONAL
Executive Officer
Theodore F. Craver, Jr.
W. James Scilacci
Adam S. Umanoff
Janet T. Clayton
Ronald O. Nichols
J. Andrew Murphy
Gaddi H. Vasquez
Pedro J. Pizarro
Ronald L. Litzinger
Age at
December 31, 2015
Company Position
64
60
56
61
62
54
60
50
56
Chairman of the Board, President and Chief Executive Officer
Executive Vice President and Chief Financial Officer
Executive Vice President and General Counsel
Senior Vice President, Corporate Communications
Senior Vice President, Regulatory Affairs, SCE
Senior Vice President, Strategic Planning
Senior Vice President, Government Affairs
President, SCE
Executive Vice President
As set forth in Article IV of Edison International's and the relevant subsidiary's Bylaws, the elected officers of Edison
International and its subsidiaries are chosen annually by, and serve at the pleasure of, Edison International and the relevant
subsidiary'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 and its subsidiaries have
been actively engaged in the business of Edison International and its subsidiaries for more than five years, except for
Mssrs. Umanoff, Nichols, and Murphy and Ms. Clayton, 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
Theodore F. Craver, Jr.
W. James Scilacci
Adam S. Umanoff
Janet T. Clayton
Ronald O. Nichols
J. Andrew Murphy
Gaddi H. Vasquez
Pedro J. Pizarro
Ronald L. Litzinger
Company Position
Chairman of the Board, President and Chief
Executive Officer, Edison International
Executive Vice President, Chief Financial Officer
Executive Vice President, Chief Financial Officer and
Treasurer, Edison International
Executive Vice President and General Counsel
Edison International
Partner, Akin Gump Strauss Hauer & Feld1
Partner, Chadbourne & Parke, LLP2
Senior Vice President, Corporate Communications,
Edison International
Senior Vice President, Corporate Communications, SCE
President, Think Cure3
Senior Vice President, Regulatory Affairs, SCE
General Manager/Chief Executive Officer, Los Angeles Department of
Water and Power4
Senior Vice President, Strategic Planning, Edison International
Senior Managing Director, Macquarie Infrastructure and Real Assets5
Executive Vice President, Strategy and M&A, NRG Energy, Inc.6
Executive Vice President & President, NE Region, NRG Energy, Inc.6
Senior Vice President, Government Affairs, Edison International and
SCE
Senior Vice President, Public Affairs, SCE
President, SCE
President, EME7
President, Edison Energy Group, Inc. and
Executive Vice President, Edison International
President, SCE
Effective Dates
August 2008 to present
September 2014 to present
August 2008 to September 2014
January 2015 to present
May 2011 to December 2014
May 2007 to May 2011
April 2011 to present
April 2013 to present
Jan 2008 to April 2011
April 2014 to present
January 2011 to February 2014
September 2015 to present
January 2012 to August 2015
August 2011 to November 2012
February 2009 to July 2011
May 2013 to present
July 2009 to May 2013
October 2014 to present
January 2011 to March 2014
October 2014 to present
January 2011 to September 2014
1 Akin Gump Strauss Hauer & Feld is a global law firm and is not a parent, affiliate or subsidiary of Edison International.
2 Chadbourne & Parke, LLP is a global law firm and is not a parent, affiliate or subsidiary of Edison International.
3 Think Cure is a community-based nonprofit organization that raises funds to accelerate collaborative research to cure cancer and is not
a parent, affiliate or subsidiary of Edison International.
119
4 Los Angeles Department of Water and Power is a municipal water and power utility company and is not a parent, affiliate or subsidiary
of Edison International.
5 Macquarie Infrastructure and Real Assets is a global infrastructure management company and is not a parent, affiliate or subsidiary of
Edison International.
6 NRG Energy, Inc. is an integrated energy company and is not a parent, affiliate or subsidiary of Edison International.
7 EME is a wholly-owned subsidiary of Edison International and an affiliate of SCE. EME filed for bankruptcy on December 17, 2012.
EXECUTIVE OFFICERS OF SOUTHERN CALIFORNIA EDISON COMPANY
Executive Officer
Pedro J. Pizarro
Maria Rigatti
Russell C. Swartz
Peter T. Dietrich
Stuart R. Hemphill
Ronald O. Nichols
Kevin M. Payne
Age at
December 31, 2015
50
52
64
51
52
62
55
Company Position
President
Senior Vice President and Chief Financial Officer
Senior Vice President and General Counsel
Senior Vice President, Transmission and Distribution
Senior Vice President, Power Supply and Operational Services
Senior Vice President, Regulatory Affairs
Senior Vice President, Customer Service
As set forth in Article IV of SCE's Bylaws, the elected officers of SCE are chosen annually by, and serve at the pleasure of,
SCE'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 above officers have been actively engaged in the business
of SCE, its parent company Edison International, and/or one of SCE's subsidiaries or other affiliates for more than five
years, except for Mssrs. Dietrich, and Nichols, 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 Officer
Pedro Pizarro
Maria Rigatti
Company Position
President, SCE
President, EME1
Senior Vice President and Chief Financial Officer, SCE
President, Edison Mission Reorganization Trust (EME Reorg Trust)2
Senior Vice President, Chief Financial Officer, EME1
Vice President, Chief Financial Officer and Treasurer, EME1
Russell C. Swartz
Senior Vice President and General Counsel, SCE
Vice President and Associate General Counsel, SCE
Peter T. Dietrich
Senior Vice President, Transmission & Distribution, SCE
Chief Nuclear Officer, SCE
Senior Vice President, SCE
Effective Dates
October 2014 to present
January 2011 to March 2014
July 2014 to present
April 2014 to June 2014
March 2011 to March 2014
December 2010 to February 2011
February 2011 to present
February 2010 to February 2011
December 2013 to present
December 2010 to December 2013
November 2010 to December 2013
Stuart R. Hemphill
Senior Vice President, Power Supply & Operational Services, SCE
Senior Vice President, Power Supply, SCE
July 2014 to present
January 2011 to July 2014
Ronald O. Nichols
Kevin M. Payne
Senior Vice President, Regulatory Affairs, SCE
General Manager/Chief Executive Officer, Los Angeles Department of
Water and Power3
Senior Vice President, Customer Service, SCE
Vice President, Engineering & Technical Services, SCE
Vice President, Client Service Planning and Controls, SCE
April 2014 to present
January 2011 to February 2014
March 2014 to present
September 2011 to March 2014
October 2010 to August 2011
1 EME is a wholly-owned subsidiary of Edison International and an affiliate of SCE. EME filed for bankruptcy on December 17, 2012.
2 EME Reorg Trust is an entity formed as part of the EME bankruptcy to hold creditors' interests after the sale of EME's assets to NRG
and is not a parent, affiliate or subsidiary of SCE.
3 Los Angeles Department of Water and Power is a municipal water and power utility company and is not a parent, affiliate or
subsidiary of SCE.
120
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information concerning executive officers of Edison International is set forth above under "Executive Officers of Edison
International." Other information responding to this section will appear in Edison International's and SCE's definitive 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.
In December 2015, the Edison International Board of Directors adopted revisions to the Edison International Bylaws that
provided shareholders with proxy access for director elections at annual meetings. The Bylaws provide that Edison
International will include in its Proxy Statement up to two nominees (or nominees for up to 20% of the Edison International
Board, whichever is greater) submitted by a shareholder or group of up to 20 shareholders owning at least 3% of the Edison
International common stock continuously for at least three years, if the shareholder group and nominee satisfy the
requirements of the Edison International Bylaws.
EXECUTIVE COMPENSATION
Information responding to this section will appear in the Joint Proxy Statement under the headings "Compensation
Discussion and Analysis," "Compensation Committee Interlocks and Insider Participation," "Executive Compensation"
"Director Compensation" and "Compensation Committee Report," 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 Joint Proxy Statement under the heading "Our Stock Ownership," and
is incorporated herein by this reference.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Information responding to this section will appear in the Joint Proxy Statement under the headings "Certain Relationships and
Related Transactions," and "Our Corporate Governance—Is SCE subject to the same corporate governance stock exchange
rules as EIX?", "—How does the Board determine which directors are independent?", "—Which directors has the Board
determined are independent to serve on the Board?" and "Where can I find the Company's corporate governance documents?"
and is incorporated herein by this reference.
PRINCIPAL ACCOUNTANT FEES AND SERVICES
Information responding to this section will appear in the Joint Proxy Statement under the heading "Independent Auditor
Fees," and is incorporated herein by this reference.
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER
PURCHASES OF EQUITY SECURITIES.
Edison International Common Stock is traded on the New York Stock Exchange under the symbol "EIX."
Market information responding to this section is included in "Notes to Consolidated Financial Statements—Note 18.
Quarterly Financial Data (Unaudited)." There are restrictions on the ability of Edison International's subsidiaries 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—Edison International Parent and Other,"
and in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividend
Restrictions." The number of common stockholders of record of Edison International was 35,375 on February 19, 2016.
Additional information concerning the market for Edison International's Common Stock is set forth on the cover page of this
report. Required information about Edison International's equity compensation plans will appear in the Joint Proxy Statement
under the heading "Item 4: Approval of an Amendment to the EIX 2007 Performance Incentive Plan," and is incorporated
herein by this reference.
121
Purchases of Equity Securities by Edison International and Affiliated Purchasers
The following table contains information about all purchases of Edison International Common Stock made by or on behalf of
Edison International in the fourth quarter of 2015.
(a) Total
Number of
Shares
(or Units)
Purchased1
177,100
210,165
164,801
552,066
(b) Average
Price Paid per
Share (or Unit)1
62.90
$
60.11
59.79
60.91
$
(c) Total
Number of Shares
(or Units)
Purchased
as Part of
Publicly
Announced
Plans or
Programs
—
—
—
—
(d) Maximum
Number (or
Approximate
Dollar Value)
of Shares
(or Units) that May
Yet Be Purchased
Under the Plans or
Programs
—
—
—
—
Period
October 1, 2015 to October 31, 2015
November 1, 2015 to November 30, 2015
December 1, 2015 to December 31, 2015
Total
1 The shares were purchased by agents acting on Edison International's behalf for delivery to plan participants to fulfill requirements in
connection with Edison International's: (i) 401(k) Savings Plan; (ii) Dividend Reinvestment and Direct Stock Purchase Plan; and
(iii) long-term incentive compensation plans. The shares were purchased in open-market transactions pursuant to plan terms or
participant elections. The shares were never registered in Edison International's name and none of the shares purchased were retired as a
result of the transactions.
Purchases of Equity Securities by Southern California Edison and Affiliated Purchasers
Information with respect to frequency and amount of cash dividends is included in "Notes to the Consolidated Financial
Statements—Note 18. Quarterly Financial Data (Unaudited)." 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.
Information on securities authorized for issuance under equity compensation plans, is not applicable because SCE has no
compensation plans under which equity securities of SCE are authorized for issuance.
122
Comparison of Five-Year Cumulative Total Return
Edison International
S & P 500 Index
Philadelphia Utility Index
At December 31,
2010
2011
2012
2013
2014
2015
$ 100
$ 111
$ 125
$ 131
$ 191
$ 177
100
100
102
119
118
119
157
132
178
170
181
159
Note: Assumes $100 invested on December 31, 2010 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.
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a)(1) Financial Statements
See Consolidated Financial Statements listed in the Table of Contents of this report.
(a)(2) Report of Independent Registered Public Accounting Firm and Schedules Supplementing Financial Statements
The following documents may be found in this report at the indicated page numbers under the heading "Exhibits and
Financial Statement Schedules" in the Table of Contents of this report.
Reports of Independent Registered Public Accounting Firm
Schedule I – Condensed Financial Information of Edison International Parent
Schedule II – Valuation and Qualifying Accounts of Edison International and SCE
Schedules I for SCE and Schedules III through V, inclusive, for both Edison International and SCE are omitted as not
required or not applicable.
(a)(3) Exhibits
See "Exhibit Index" in this report.
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.
123
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,
2015
2014
$
7
$
259
266
8
531
539
12,696
12,416
$
$
626
111
13,699
646
214
368
1,228
399
704
$
$
547
172
13,674
619
204
377
1,200
610
904
11,368
10,960
$
13,699
$
13,674
124
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF INCOME
For the Years Ended December 31, 2015, 2014 and 2013
(in millions)
2015
2014
2013
Operating revenue and other income
$
3
$
3
$
Operating expenses and interest expense
Loss before equity in earnings of subsidiaries
Equity in earnings of subsidiaries
Income before income taxes
Income tax benefit
Income from continuing operations
Income from discontinued operations, net of tax
78
(75)
1,025
950
(35)
985
35
94
(91)
1,482
1,391
(36)
1,427
185
Net income
$
1,020
$
1,612
$
—
72
(72)
922
850
(29)
879
36
915
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
For the Years Ended December 31, 2015, 2014 and 2013
(in millions)
Net income
Other comprehensive income (loss), net of tax
Comprehensive income
2015
2014
2013
$
$
1,020
2
1,022
$
$
1,612
(45)
1,567
$
$
915
74
989
125
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF CASH FLOWS
For the Years Ended December 31, 2015, 2014 and 2013
(in millions)
Net cash provided by (used in) operating activities
Cash flows from financing activities:
Payable due to affiliate
Short-term debt financing, net
Settlements of stock-based compensation, net
Dividends paid
Net cash (used in) provided by financing activities
Net cash used in 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
2015
2014
2013
$
641
$
(73)
$
387
54
26
(42)
(544)
(506)
(136)
(1)
8
66
584
(24)
(463)
163
(95)
(5)
13
$
7
$
8
$
10
33
(6)
(440)
(403)
(35)
(51)
64
13
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's Parent 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 $758 million, $378 million and $486 million in 2015, 2014
and 2013, respectively.
Dividend Restrictions
The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make
distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above
the 48% on a 13-month weighted average basis. At December 31, 2015, SCE's 13-month weighted-average common equity
component of total capitalization was 49.9% and the maximum additional dividend that SCE could pay to Edison
International under this limitation was approximately $441 million, resulting in a restriction on SCE's net assets of
$13.2 billion.
Note 2. Debt and Credit Agreements
Long-Term Debt
At December 31, 2015 and 2014, Edison International Parent had 3.75% senior notes outstanding of $400 million, which
matures in 2017. In connection with a settlement agreement between Edison International, EME and the Consenting
Noteholders, in September 2014, Edison International Parent issued non-interest bearing promissory notes of which
$204 million was paid on September 30, 2015 and $214 million is due on September 30, 2016.
Credit Agreements and Short-Term Debt
In 2015, Edison International Parent amended the credit facility to extend the maturity date for the $1.25 billion credit facility
to July 2020. At December 31, 2015, the outstanding commercial paper was $646 million at a weighted-average interest rate
of 0.78%. This short-term debt was supported by the $1.25 billion multi-year revolving credit facility. At December 31, 2014,
the outstanding commercial paper was $619 million at a weighted-average interest rate of 0.45%.
126
The following table summarizes the status of the credit facility at December 31, 2015:
(in millions)
Commitment
Outstanding borrowings
Amount available
$
$
1,250
(646)
604
The debt covenant in Edison International's credit facility requires a consolidated debt to total capitalization ratio of less than
or equal to 0.65 to 1. The ratio is defined in the credit agreement and generally excluded the consolidated debt and total
capital of EME during the periods it was consolidated for financial reporting purposes. At December 31, 2015, Edison
International's consolidated debt to total capitalization ratio was 0.47 to 1.
Note 3. Related-Party Transactions
Edison International's Parent expenses from services provided by SCE were $3 million annually in 2015, 2014 and 2013.
Edison International Parent had current related-party receivables of $252 million and $267 million and current related-party
payables of $149 million and $213 million at December 31, 2015 and 2014, respectively. Edison International Parent had
long-term related-party receivables of $105 million and $125 million at December 31, 2015 and 2014, respectively, and
long-term related-party payables of $213 million and $179 million at December 31, 2015 and 2014, respectively.
Note 4. Contingencies
For a discussion of material contingencies see "Notes to Consolidated Financial Statements—Note 7. Income Taxes,"
"—Note 11. Commitments and Contingencies" and "—Note 15. Discontinued Operations."
127
EDISON INTERNATIONAL
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
46.2
25.1
71.3
32.0
48.9
23.3
72.2
29.0
52.2
17.8
70.0
1,380
(in millions)
For the Year ended December 31, 2015
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible amounts
Tax valuation allowance
For the Year ended December 31, 2014
Allowance for uncollectible accounts
Customers
All others
Additions
Balance at
Beginning
of
Period
Charged to
Costs and
Expenses
Charged to
Other
Accounts
Deductions
Balance at
End of
Period
$
$
$
$
$
$
$
$
48.9
23.3
72.2
29.0
52.2
17.8
$
$
$
$
23.9
23.0
46.9
3.0
24.1
19.7
— $
—
— $
— $
26.6
$
21.2
47.8 a $
— $
— $
27.4
$
—
— $
— $
14.2
41.6 a $
1,351 c $
Total allowance for uncollectible amounts
Tax valuation allowance
$
70.0
$
$ 1,380.0 b $
43.8
$
— b $
For the Year ended December 31, 2013
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible amounts
Tax valuation allowance
a Accounts written off, net.
$
$
46.6
79.5
126.1
$ 1,016.5
$
$
$
36.0
19.3
55.3
$
363.5 b $
$
— $
30.4
$
—
— $
— $
81.0
111.4 a $
— $
b Edison International recorded deferred tax assets of $2.2 billion related to net operating losses and tax carryforwards that pertain to
Edison International's consolidated or combined federal and state tax returns, including approximately $1.6 billion related to EME.
Edison International continues to consolidate EME for federal and certain combined state tax returns. EME's Plan of Reorganization,
filed in December 2013 ("December Plan of Reorganization"), provides for the transfer of EIX's ownership interest to the creditors,
which would result in a tax deconsolidation of EME. Under federal and state tax regulations, the tax deconsolidation of EME would
reduce the amounts of net operating loss and tax credits carryforwards that Edison International would be eligible to use in future
periods. As a result of the EME's December Plan of Reorganization, which would result in a tax deconsolidation of EME, Edison
International has recorded a $1.380 billion valuation allowance based on the estimated amount of such benefits as calculated under the
applicable federal and state tax regulations as of December 31, 2013. The deferred income tax benefits recognized by Edison
International less the valuation allowance for amounts that would no longer be available upon tax deconsolidation of EME was
approximately $220 million.
c On April 1, 2014, under the Amended Plan of Reorganization, EME emerged from bankruptcy free of liabilities but remained an
indirect wholly-owned subsidiary of Edison International, which will continue to be consolidated with Edison International for income
tax purposes. Edison International anticipates realization of the federal and California tax benefits before they expire. Therefore, the
valuation allowance on federal and California tax benefits that Edison International recorded in 2013 was released in 2014. The
remaining valuation allowance is related to non California state tax benefits.
128
SOUTHERN CALIFORNIA EDISON COMPANY
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
(in millions)
For the Year ended December 31, 2015
For the Year ended
Customers
All others
Total allowance for uncollectible accounts
For the Year ended December 31, 2014
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible accounts
For the Year ended December 31, 2013
Allowance for uncollectible accounts
Customers
All others
Total allowance for uncollectible accounts
a Accounts written off, net.
Additions
Balance at
Beginning
of
Period
Charged to
Costs and
Expenses
Charged to
Other
Accounts
Deductions
Balance at
End of
Period
$
$
$
$
$
$
48.9
18.7
67.6
52.2
13.3
65.5
46.6
28.3
74.9
$
$
$
$
$
$
23.9
18.0
41.9
24.1
19.6
43.7
36.0
19.3
55.3
$
$
$
$
$
$
— $
—
— $
26.6
$
21.2
47.8 a $
46.2
15.5
61.7
— $
—
— $
27.4
$
14.2
41.6 a $
48.9
18.7
67.6
— $
—
— $
30.4
$
34.3
64.7 a $
52.2
13.3
65.5
129
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/ Mark C. Clarke
By:
/s/ Connie J. Erickson
Mark C. Clarke
Vice President and Controller
(Duly Authorized Officer and
Principal Accounting Officer)
Connie J. Erickson
Vice President and Controller
(Duly Authorized Officer and
Principal Accounting Officer)
Date: February 23, 2016
Date: February 23, 2016
130
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
Theodore F. Craver, Jr.*
Pedro J. Pizarro*
B. Principal Financial Officers
W. James Scilacci*
Title
Chairman of the Board, President,
Chief Executive Officer and Director
(Edison International)
President and Director
(Southern California Edison Company)
Executive Vice President and Chief Financial Officer
(Edison International)
Maria Rigatti*
Senior Vice President and Chief Financial Officer
(Southern California Edison Company)
C. Principal Accounting Officers
Mark C. Clarke
Connie J. Erickson
D. Directors (Edison International and
Southern California Edison Company,
unless otherwise noted)
Jagjeet S. Bindra*
Vanessa C.L. Chang*
Theodore F. Craver, Jr.*
Pedro J. Pizarro (SCE only)*
Richard T. Schlosberg, III*
Linda G. Stuntz*
William P. Sullivan*
Ellen O. Tauscher*
Peter J. Taylor*
Brett White*
Vice President and Controller
(Edison International)
Vice President and Controller
(Southern California Edison Company)
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
*By:
/s/ Mark C. Clarke
*By:
/s/ Connie J. Erickson
Mark C. Clarke
Vice President and Controller
(Attorney-in-fact for EIX Directors and Officers)
Connie J. Erickson
Vice President and Controller
(Attorney-in-fact for SCE Directors and Officers)
Date: February 23, 2016
Date: February 23, 2016
131
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 December 10, 2015 (File No. 1-9936, filed as Exhibit 3.1 to Edison
International's Form 8-K dated December 10, 2015 and filed December 14, 2015)*
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 Southern California Edison Company's Form 10-Q for the quarter ended September 30, 2015)*
Bylaws of Southern California Edison Company, as amended June 21, 2012 (File No. 1-2313, filed as Exhibit 3.1
to Southern California Edison Company's Form 8-K dated June 21, 2012 and filed June 22, 2012)*
Edison International
4.1
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
4.2
4.3
Southern California Edison Company First Mortgage Bond Trust Indenture, dated as of October 1, 1923 (File
No. 1-2313, filed as Exhibit 4.2 to Southern California Edison Company'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, Form 8-K dated
January 28, 1993)*
Edison International
10.1**
10.2**
10.3**
10.3.1**
10.3.2**
10.4**
10.5**
10.6**
10.6.1**
10.7**
10.8**
Edison International Director Deferred Compensation Plan as amended effective June 19, 2014 (File No. 1-9936,
filed as Exhibit 10.3 for the quarter ended June 30, 2014)*
Edison International 2008 Director Deferred Compensation Plan, as amended and restated effective June 19, 2014
(File No. 1-9936, filed as Exhibit No. 10.2 for the quarter ended June 30, 2014)*
Director Grantor Trust Agreement, dated August 1995 (File No. 1-9936, filed as Exhibit 10.10 to Edison
International's Form 10-K for the year ended December 31, 1995)*
Director Grantor Trust Agreement Amendment 2002-1, effective May 14, 2002 (File No. 1-9936, filed as
Exhibit 10.4 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)*
Edison International Executive Deferred Compensation Plan, as amended and restated effective June 19, 2014
(File No. 1-9936, filed as Exhibit 10.4 for the quarter ended June 30, 2014)*
Edison International 2008 Executive Deferred Compensation Plan, as amended and restated effective
December 9, 2015
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)*
Southern California Edison Company Executive Supplemental Benefit Program, as amended effective
February 25, 2015 (File No. 1-9936, filed as Exhibit No. 10.4 for the quarter ended March 31, 2015)*
Southern California Edison Company Executive Retirement Plan, as amended effective June 19, 2014 (File No.
1-9936, filed as Exhibit 10.7 for the quarter ended June 30, 2014)*
10.8.1**
Edison International 2008 Executive Retirement Plan, as amended and restated effective December 9, 2015
10.9**
Edison International Executive Incentive Compensation Plan, as amended and restated effective February 25,
2015 (File No. 1-9936, filed as Exhibit No. 10.3 to Edison International's Form 10-Q for the quarter ended
March 31, 2015)*
132
Exhibit
Number
10.10**
10.11**
Description
Edison International 2008 Executive Disability Plan, as amended and restated effective June 19, 2014 (File No.
1-9936, filed as Exhibit No. 10.9 to Edison International's Form 10-Q for the quarter ended June 30, 2014)*
Edison International 2008 Executive Survivor Benefit Plan, as amended and restated effective June 19, 2014 (File
No. 1-9936, filed as Exhibit No. 10.10 to Edison International's Form 10-Q for the quarter ended June 30, 2014)*
10.11.1**
Termination of Edison International 2008 Executive Survivor Benefit Plan, adopted on December 9, 2015
10.12**
10.13**
Retirement Plan for Directors, as amended and restated effective December 31, 2008 (File No. 1-9936 filed as
Exhibit No. 10.17 to Edison International's Form 10-K for the year ended December 31, 2008)*
Equity Compensation Plan as restated effective January 1, 1998 (File No. 1-9936, filed as Exhibit 10.1 to Edison
International's Form 10-Q for the quarter ended June 30, 1998)*
10.13.1**
Equity Compensation Plan Amendment No. 1, effective May 18, 2000 (File No. 1-9936, filed as Exhibit 10.4 to
Edison International's Form 10-Q for the quarter ended June 30, 2000)*
10.13.2** Amendment of Equity Compensation Plans, adopted October 25, 2006 (File No. 1-9936, filed as Exhibit 10.52 to
Edison International's Form 10-K for the year ended December 31, 2006)*
10.14**
10.15**
2000 Equity Plan, effective May 18, 2000 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's
Form 10-Q for the quarter ended June 30, 2000)*
Edison International 2007 Performance Incentive Plan as amended and restated in February 2011 (File
No. 1-9936, filed as Exhibit 10.2 to the Edison International Form 10-Q for the quarter ended June 30, 2011)*
10.15.1**
Edison International 2008 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, 2008)*
10.15.2**
Edison International 2009 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, 2009)*
10.15.3**
Edison International 2010 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.2 to
Edison International's Form 10-Q for the quarter ended March 31, 2010)*
10.15.4**
Edison International 2011 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.2 to
Edison International's Form 10-Q for the quarter ended March 31, 2011)*
10.15.5**
Edison International 2012 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.2 to
Edison International's Form 10-Q for the quarter ended March 31, 2012)*
10.15.6**
Edison International 2013 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.2 to
Edison International's Form 10-Q for the quarter ended March 31, 2013)*
10.15.7**
Edison International 2014 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.3 to
Edison International's Form 10-Q for the quarter ended March 31, 2014)*
10.15.8**
Edison International 2015 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.2 to
Edison International's Form 10-Q for the quarter ended March 31, 2015)*
10.16.1**
10.16.2**
10.16.3**
10.17**
10.18**
Terms and conditions for 2005 long-term compensation award under the Equity Compensation Plan and 2000
Equity Plan (File No. 1-9936, filed as Exhibit 99.2 to Edison International's Form 8-K dated December 16, 2004
and filed on December 22, 2004)*
Terms and conditions for 2006 long-term compensation awards under the Equity Compensation Plan and 2000
Equity Plan (File No. 1-9936, filed as Exhibit 10.29 to Edison International's Form 10-K for the year ended
December 31, 2005)*
Terms and conditions for 2007 long-term compensation awards under the Equity Compensation Plan and the 2007
Performance Incentive Plan (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the
quarter ended March 31, 2007)*
Director Nonqualified Stock Option Terms and Conditions under the 2007 Performance Incentive Plan
(File 1-9936, filed as Exhibit 10.2 to Edison International's Form 10-Q for the quarter ended March 31, 2007)*
Edison International and Edison Mission Energy Affiliate Option Exchange Offer Summary of Deferred
Compensation Alternatives, dated July 3, 2000 (File No. 1-13434, filed as Exhibit 10.94 to the Edison Mission
Energy's Form 10-K for the year ended December 31, 2001)*
133
Exhibit
Number
10.18.1**
10.19**
10.20**
10.21**
10.22**
10.23
10.23.1
10.23.2
10.23.3
10.23.4
10.23.5
10.24**
10.25**
10.26**
Description
Edison International and Edison Mission Energy Affiliate Option Exchange Offer Circular, dated July 3, 2000
(File No. 1-13434, filed as Exhibit 10.93 to the Edison Mission Energy's Form 10-K for the year ended
December 31, 2001)*
Edison International 2008 Executive Severance Plan, as amended and restated effective February 25, 2015 (File
No. 1-9936, filed as Exhibit 10.6 for the quarter ended March 31, 2015)*
Edison International and Southern California Edison Company Director Compensation Schedule, as adopted
June 17, 2015 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended
June 30, 2015)*
Edison International Director Matching Gifts Program, as adopted June 24, 2010 (File No. 1-9936, filed as
Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended June 30, 2010*
Edison International Director Nonqualified Stock Options 2005 Terms and Conditions (File No. 1-9936, filed as
Exhibit 99.3 to Edison International's Form 8-K dated May 19, 2005, and filed on May 25, 2005)*
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 Edison Capital and Edison Funding Company
(formerly Mission First Financial and Mission Funding Company) dated May 1, 1995 (File No. 1-9936, filed as
Exhibit 10.3.2 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)*
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 period ended June 30, 2005, and filed on August 9, 2005)*
Edison International 2015 Executive Annual Incentive Program (File No. 1-9936, filed as Exhibit 10.1 to Edison
International's Form 10-Q for the quarter ended March 31, 2015)*
Section 409A and Other Conforming Amendments to Terms and Conditions (File No. 1-9936, filed as Exhibit
No. 10.37 to Edison International's Form 10-K for the year ended December 31, 2008)*
10.26.1**
Section 409A Amendments to Director Terms and Conditions (File No. 1-9936, filed as Exhibit No. 10.37.1 to
Edison International's Form 10-K for the year ended December 31, 2008)*
10.27
10.28
10.29
21
23.1
Amended and Restated Credit Agreement, dated as of July 14, 2015 among Edison International and the Lenders
named therein (File 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated July 14, 2015 and filed
July 17, 2015)*
Amended and Restated Credit Agreement, dated as of July 14, 2015, among Southern California Edison Company
and the Lenders named therein (File 1-2313, filed as Exhibit 10.2 to Southern California Edison Company's Form
8-K dated July 14, 2015 and filed July 17, 2015)*
Amended and Restated Settlement Agreement between Southern California Edison Company, San Diego Gas &
Electric Company, the Office of Ratepayer Advocates, The Utility Reform Network, Friends of the Earth, and the
Coalition of California Utility Employees, dated September 23, 2014 (File No. 1-9936, filed as Exhibit 10.1 to
Edison International's Form 10-Q for the quarter ended September 30, 2014)*
Subsidiaries of the Registrants
Consent of Independent Registered Public Accounting Firm (Edison International)
134
Exhibit
Number
23.2
24.1
24.2
31.1
31.2
32.1
32.2
101.1
101.2
Description
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, 2015, filed on February 23, 2016, formatted in 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, 2015, filed on February 23, 2016, formatted in 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
________________________________________
*
Incorporated by reference pursuant to Rule 12b-32.
** Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3).
135
Edison International and Southern California Edison 2015 Annual Report
BOARD OF DIRECTORS
EDISON INTERNATIONAL
Ellen O. Tauscher 1,3
Strategic Advisor,
Baker, Donelson, Bearman,
Caldwell & Berkowitz
Director since 2013
Peter J. Taylor 1,2
President,
ECMC Foundation
Director since 2011
Brett White 2,4
Chairman and
Chief Executive Officer,
Cushman & Wakefield
Director since 2007
1 Audit Committee
2 Compensation and Executive
Personnel Committee
3 Finance, Operations and
Safety Oversight Committee
4 Nominating/Corporate Governance
Committee
Theodore F. Craver, Jr.
Chairman of the Board,
President and
Chief Executive Officer
Director of EIX since 2007
Director of SCE since 2008
Pedro J. Pizarro
President,
Southern California Edison
Director of SCE since 2014
Jagjeet S. Bindra1,3
Retired President,
Chevron Global Manufacturing
Director since 2010
Vanessa C.L. Chang1,2
Director,
EL & EL Investments
Director since 2007
Richard T. Schlosberg, III 2,4
Retired President and
Chief Executive Officer,
The David and Lucile Packard
Foundation
Director since 2002
Linda G. Stuntz 3,4
Partner,
Stuntz, Davis & Staffier, P.C.
Director since 2014
William P. Sullivan 3,4
Retired Chief Executive Officer,
Agilent Technologies
Director since 2015
Theodore F. Craver, Jr.
Chairman of the Board,
President and
Chief Executive Officer
Ronald L. Litzinger
Executive Vice President
W. James Scilacci
Executive Vice President and
Chief Financial Officer
Adam S. Umanoff
Executive Vice President and
General Counsel
Janet T. Clayton
Senior Vice President,
Corporate Communications
J. Andrew Murphy
Senior Vice President,
Strategic Planning
Gaddi H. Vasquez
Senior Vice President,
Government Affairs
Jeffrey L. Barnett
Vice President,
Tax
Robert C. Boada
Vice President and Treasurer
Scott S. Cunningham
Vice President,
Investor Relations
David J. Heller
Vice President, Risk Management
and Insurance, and General Auditor
Barbara E. Mathews
Vice President,
Associate General Counsel,
Chief Governance Officer and
Corporate Secretary
Michael D. Montoya
Vice President and
Chief Ethics and
Compliance Officer
Aaron D. Moss
Vice President and
Controller
Oded J. Rhone
Vice President,
Strategic Planning
42649 Merrill.indd 1
3/1/16 3:05 PM
Edison International and Southern California Edison 2015 Annual Report
SOUTHERN CALIFORNIA EDISON
EDISON ENERGY GROUP
Ronald L. Litzinger
President,
Edison Energy Group
Lloyd J. MacNeil
General Counsel,
Edison Energy Group
Mark C. Clarke
Vice President,
Group Controller and Treasurer
Edison Energy Group
Steven D. Eisenberg
President,
Edison Transmission
Nicole Neeman Brady
President,
Edison Water Resources
Robert Scheuermann
President,
SoCore Energy
Allan J. Schurr
President,
Edison Energy
Pedro J. Pizarro
President
Janet T. Clayton
Senior Vice President,
Corporate Communications
Peter T. Dietrich
Senior Vice President,
Transmission & Distribution
Stuart R. Hemphill
Senior Vice President,
Power Supply & Operational Services
Todd L. Inlander
Senior Vice President and
Chief Information Officer
Ronald O. Nichols
Senior Vice President,
Regulatory Affairs and Nuclear
Kevin M. Payne
Senior Vice President,
Customer Service
Maria Rigatti
Senior Vice President and
Chief Financial Officer
Russell C. Swartz
Senior Vice President and
General Counsel
Gaddi H. Vasquez
Senior Vice President,
Government Affairs
Jeffrey L. Barnett
Vice President,
Tax
Douglas R. Bauder
Vice President,
Operational Services
Lisa D. Cagnolatti
Vice President,
Business Customer Division
Caroline Choi
Vice President,
Energy and
Environmental Policy
Colin E. Cushnie
Vice President,
Energy Procurement & Management
Chris C. Dominski
Vice President,
Operational Finance
Connie J. Erickson
Vice President and Controller
Gregory M. Ferree
Vice President,
Distribution
Paul J. Grigaux
Vice President,
Transmission, Substations
and Operations
Veronica Gutierrez
Vice President,
Local Public Affairs
Philip Herrington
Vice President,
Power Production
Nestor Martinez
Vice President,
Engineering & Technical Services
Barbara E. Mathews
Vice President,
Associate General Counsel,
Chief Governance Officer and
Corporate Secretary
Patricia H. Miller
Vice President,
Human Resources
Michael D. Montoya
Vice President and
Chief Ethics and Compliance Officer
Thomas J. Palmisano
Vice President and
Chief Nuclear Officer
William M. Petmecky, III
Vice President and Treasurer
Steven D. Powell
Vice President,
Strategy & Integrated Planning
Abdou Terki-Hassaine
Vice President,
Customer Service Operations
Marc L. Ulrich
Vice President,
Customer Programs & Services
42649 Merrill.indd 2
3/1/16 3:05 PM
2015 FINANCIAL HIGHLIGHTS
Dollar amounts in millions, except per-share data
Years ended December 31,
Operating revenue
Core earnings (1)
Less: non-core items:
2015
2014
2013
$11,524 $13,413 $12,581
$1,237
$1,497
$1,336
Write-down, impairment and other charges
Discontinued operations
Other items
Total non-core items
Basic earnings(1)
Core earnings per share (1)
Basic earnings per share (1)
(382)
36
35
7
31
115 (322)
(316)
$915
$1,612
$1,020
$4.10
$3.80
$4.59
$3.13 $4.95 $2.81
(72) (365)
185
2
Total assets at December 31
Dividends paid per common share
Total shareholder return
Total employees
$50,310 $49,734 $46,225
$1.35
$1.42
$1.67
(6.9)% 45.0% 5.4%
13,677
13,690
12,768
BUSINESS HIGHLIGHTS
Southern California Edison
Rate base (2)
Capital expenditures (2)
Peak demand (megawatts)
Total system sales (kilowatt-hours, in millions)
$24,596
$3,867
23,079
87,544
$23,254 $21,116
$3,530
$3,967
22,534
23,055
87,397
88,986
(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 December 31, which includes capital expenditures related to certain FERC-approved
projects during the construction phase and excludes San Onofre Nuclear Generating Station. Capital expenditures for each year
include accruals.
Inquiries may also be directed to:
Wells Fargo Shareowner Services
1110 Centre Point Curve, Suite 101
Mendota Heights, MN 55120-4100
Fax:
(651) 450-4033
Wells Fargo Shareowner ServicesSM
www.shareowneronline.com
Investor Relations
www.edisoninvestor.com
Email: invrel@sce.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 Wells Fargo Shareowner
Services upon request
EDISON INTERNATIONAL
Annual Meeting
The annual meeting of shareholders
will be held on Thursday, April 28,
2016, at 9:00 a.m., Pacific Time, at
the Hilton Los Angeles San Gabriel
Hotel, 225 West Valley Boulevard,
San Gabriel, California 91776.
Corporate Governance Practices
A description of Edison International’s
corporate governance practices is
available on our Web site at
www.edisoninvestor.com. The Edison
International Board Nominating/
Corporate Governance Committee
periodically reviews the Company’s
corporate governance practices and
makes recommendations to the
Company’s Board that the practices
be updated from time to time.
Stock Listing and Trading Information
Common Stock: The New York Stock
Exchange uses the ticker symbol EIX;
daily newspapers list the stock as
EdisonInt.
SCE’s 4.08%, 4.24%, 4.32% and
4.78% Series of $25 par value
cumulative preferred stock are listed
on the NYSE MKT stock exchange.
Shares of SCE’s preference stock are
not listed on an exchange. SCE Trust I,
SCE Trust II, SCE Trust III and SCE
Trust IV, subsidiaries of SCE, have
issued Trust Preference Securities
which are listed on the New York
Stock Exchange.
Transfer Agent and Registrar
Wells Fargo Bank, N.A., which maintains
shareholder records, is the transfer
agent and registrar for Edison
International’s common stock and
Southern California Edison Company’s
preferred and preference stock.
Shareholders may call Wells Fargo
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
Modernizing the Power Network
Edison International and Southern California Edison
2015 Annual Report
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