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EDISON INTERNATIONAL - Annual Report: 2016 (Form 10-K)




 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
þ
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the fiscal year ended December 31, 2016
o
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from                        to
Commission
File Number
 
Exact Name of Registrant
as specified in its charter
 
State or Other Jurisdiction of
Incorporation or Organization
 
IRS Employer
Identification Number
1-9936
 
EDISON INTERNATIONAL
 
California
 
95-4137452
1-2313
 
SOUTHERN CALIFORNIA EDISON COMPANY
 
California
 
95-1240335
EDISON INTERNATIONAL
 
SOUTHERN CALIFORNIA EDISON COMPANY
2244 Walnut Grove Avenue
(P.O. Box 976)
Rosemead, California 91770
(Address of principal executive offices)
 
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
 
NYSE LLC
Southern California Edison Company: Cumulative Preferred Stock
 
NYSE MKT LLC
4.08% Series, 4.24% Series, 4.32% Series, 4.78% Series
 
 
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Edison International        Yes þ No o    Southern California Edison Company        Yes þ No o
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 o No þ    Southern California Edison Company        Yes o No þ
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 þ No o    Southern California Edison Company        Yes þ No o
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 þ No o    Southern California Edison Company        Yes þ No o
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        þ        Southern California Edison Company        þ
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 þ
Accelerated Filer o
Non-accelerated Filer o
Smaller Reporting Company o
Southern California Edison Company
Large Accelerated Filer o
Accelerated Filer o
Non-accelerated Filer þ
Smaller Reporting Company o
 
 
 
 
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Edison International        Yes o No þ    Southern California Edison Company        Yes o No þ
Aggregate market value of voting and non-voting common equity held by non-affiliates of the registrants as of June 30, 2016, the last business day of the most recently completed second fiscal quarter:
Edison International    Approximately $25.3 billion    Southern California Edison Company    Wholly owned by Edison International
Common Stock outstanding as of February 17, 2017:
 
 
Edison International
 
325,811,206 shares
Southern California Edison Company
 
434,888,104 shares (wholly owned by Edison International)
DOCUMENTS INCORPORATED BY REFERENCE
Designated portions of the Proxy Statement relating to registrants' joint 2017 Annual Meeting of Shareholders have been incorporated by reference into the parts of this report where indicated.
 
 
 
 
 
 







TABLE OF CONTENTS
 
 
 
 
 
SEC Form 10-K Reference Number
 
 
Part II, Item 7
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


i


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Part I, Item 1A
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Part II, Item 7A
Part II, Item 8
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


ii


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Part II, Item 6
Part II, Item 9A
Part II, Item 9B
Part II, Item 9
Part I, Item 1
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


iii


 
 
 
 
 
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.
AFUDC
 
allowance for funds used during construction
ALJ
 
administrative law judge
ARO(s)
 
asset retirement obligation(s)
Bcf
 
billion cubic feet
Bonus depreciation
 
Current federal tax deduction of a percentage of the qualifying property placed in service during periods permitted under tax laws 
BRRBA
 
Base Revenue Requirement Balancing Account
CAISO
 
California Independent System Operator
CPUC
 
California Public Utilities Commission
DOE
 
U.S. Department of Energy
DERs
 
distributed energy resources
DRP
 
Distributed Resources Plan
Edison Energy
 
Edison Energy, LLC, a wholly-owned subsidiary of Edison Energy Group that advises and provides energy solutions to large energy users
Edison Energy Group
 
Edison Energy Group, Inc., the holding company for subsidiaries engaged in competitive businesses focused on providing energy services, including distributed generation and/or storage, to commercial and industrial customers
EME
 
Edison Mission Energy
EME Settlement Agreement
 
Settlement Agreement by and among Edison Mission Energy, Edison International and the Consenting Noteholders identified therein, dated February 18, 2014
EMG
 
Edison Mission Group Inc., a wholly owned subsidiary of Edison International and the parent company of EME and Edison Capital
ERRA
 
energy resource recovery account
FERC
 
Federal Energy Regulatory Commission
GAAP
 
generally accepted accounting principles
GHG
 
greenhouse gas
GRC
 
general rate case
GWh
 
gigawatt-hours
HLBV
 
hypothetical liquidation at book value
IRS
 
Internal Revenue Service
Joint Proxy Statement
 
Edison International's and SCE's definitive Proxy Statement filed with the SEC in connection with Edison International's and SCE's Annual Shareholders' Meeting held on April 27, 2017
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
MW
 
megawatts
MWdc
 
megawatts measured for solar projects representing the accumulated peak capacity of all the solar modules
NEIL
 
Nuclear Electric Insurance Limited
NEM
 
net energy metering
NERC
 
North American Electric Reliability Corporation
NRC
 
Nuclear Regulatory Commission
ORA
 
CPUC's Office of Ratepayers Advocates
OII
 
Order Instituting Investigation
Palo Verde
 
nuclear electric generating facility located near
Phoenix, Arizona in which SCE holds a 15.8% ownership interest
PBOP(s)
 
postretirement benefits other than pension(s)
QF(s)
 
qualifying facility(ies)


v


ROE
 
return on common equity
S&P
 
Standard & Poor's Ratings Services
San Onofre
 
retired nuclear generating facility located in south
San Clemente, California in which SCE holds a 78.21% ownership interest
San Onofre OII Settlement Agreement
 
Settlement Agreement by and among TURN, ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth, dated November 20, 2014
SCE
 
Southern California Edison Company
SDG&E
 
San Diego Gas & Electric
SEC
 
U.S. Securities and Exchange Commission
SED
 
Safety and Enforcement Division of the CPUC, formerly known as the Consumer Protection and Safety Division or CPSD
SoCalGas
 
Southern California Gas Company
SoCore Energy
 
SoCore Energy LLC, a subsidiary of Edison Energy Group that provides solar energy and energy storage solutions
TURN
 
The Utility Reform Network
US EPA
 
U.S. Environmental Protection Agency



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 statements that do not directly relate to a historical or current fact. Other information distributed by Edison International and SCE that is incorporated in this report, or that refers to or incorporates this report, may also contain forward-looking statements. In this report and elsewhere, the words "expects," "believes," "anticipates," "estimates," "projects," "intends," "plans," "probable," "may," "will," "could," "would," "should," and variations of such words and similar expressions, or discussions of strategy or plans, are intended to identify forward-looking statements. Such statements necessarily involve risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of the risks, uncertainties and other important factors that could cause results to differ from those currently expected, or that otherwise could impact Edison International and SCE, include, but are not limited to the:
•
ability of SCE to recover its costs in a timely manner from its customers through regulated rates, including costs related to San Onofre and proposed spending on grid modernization;
•
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, approval of proposed spending on grid modernization, outcome of San Onofre CPUC proceedings, and delays in regulatory actions;
•
ability of Edison International or SCE to borrow funds and access the capital markets on reasonable terms;
•
risks associated with cost allocation, including the potential movement of costs to certain customers, caused by the ability of cities, counties and certain other public agencies to generate and/or purchase electricity for their local residents and businesses, along with other possible customer bypass or departure due to increased adoption of distributed energy resources ("DERs") or 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 SCE's transmission and distribution infrastructure investment program, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, power curtailment costs (payments due under power contracts in the event there is insufficient transmission to enable acceptance of power delivery), 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 decommissioning of San Onofre, including those related to public opposition, permitting, governmental approvals, and cost overruns;
•
physical security of Edison International's and SCE's critical assets and personnel and the cybersecurity of Edison International's and SCE's critical information technology systems for grid control, and business and customer data;
•
ability of Edison International to develop Edison Energy Group, 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 tax laws and regulations, at both the state and federal levels, or changes in the application of those laws; that could affect recorded deferred tax assets and liabilities and effective tax rate;
•
changes in the fair value of investments and other assets;
•
changes in interest rates and rates of inflation, including escalation rates, which may be adjusted by public utility regulators;
•
governmental, statutory, regulatory or administrative changes or initiatives affecting the electricity industry, including the market structure rules applicable to each market adopted by the NERC, CAISO, WECC and similar regulatory bodies in adjoining regions;

1


•
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;
•
cost of fuel for generating facilities and related transportation, which could be impacted by, among other things, disruption of natural gas storage facilities, to the extent not recovered through regulated rate cost escalation provisions or balancing accounts;
•
disruption of natural gas supply due to unavailability of storage facilities, which could lead to electricity service interruptions; 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. 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 Edison Energy Group, a holding company for subsidiaries engaged in pursuing competitive business opportunities across energy services and distributed solar to commercial and industrial customers. 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)
2016
 
2015
 
2016 vs 2015 Change
 
2014
Net income (loss) attributable to Edison International
 
 
 
 
 
 
 
Continuing operations
 
 
 
 
 
 
 
SCE
$
1,376

 
$
998

 
$
378

 
$
1,453

Edison International Parent and Other
(77
)
 
(13
)
 
(64
)
 
(26
)
Discontinued operations
12

 
35

 
(23
)
 
185

Edison International
1,311

 
1,020

 
291

 
1,612

Less: Non-core items
 
 
 
 
 
 
 
     SCE
 
 
 
 
 
 
 
Write-down, impairment and other charges
—

 
(382
)
 
382

 
(72
)
    NEIL insurance recoveries
—

 
12

 
(12
)
 
—

     Edison International Parent and Other
 
 
 
 
 
 
 
Edison Capital sale of affordable housing portfolio
—

 
10

 
(10
)
 
—

Income from allocation of losses to tax equity investor
5

 
9

 
(4
)
 
2

     Discontinued operations
12

 
35

 
(23
)
 
185

Total non-core items
17

 
(316
)
 
333

 
115

Core earnings (losses)
 
 
 
 
 
 
 
SCE
1,376

 
1,368

 
8

 
1,525

Edison International Parent and Other
(82
)
 
(32
)
 
(50
)
 
(28
)
Edison International
$
1,294

 
$
1,336

 
$
(42
)
 
$
1,497

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 non-core items. Non-core items include 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 gains and losses related to certain tax, regulatory or legal settlements or proceedings.
Edison International's 2016 earnings increased $291 million, driven by an increase in SCE's earnings of $378 million partially offset by increased costs at Edison International Parent and Other and lower income from discontinued operations. SCE's increased net income consisted of $8 million of higher core earnings and $370 million of higher non-core earnings. The increase in core earnings was due to an increase in revenue from the escalation mechanism set forth in the 2015 GRC decision and lower operations and maintenance expenses, partially offset by higher net financing costs and tax expense.

3



Edison International Parent and Other results for 2016 consisted of $50 million of higher core losses and $14 million of lower non-core earnings. During 2016, Edison International Parent and Other recorded an after-tax charge of $13 million related to the buy-out of an earn-out provision with the former shareholders of a company acquired by Edison Energy at the end of 2015. The buy-out was completed, together with modification to employment contracts, in order to align long-term incentive compensation. In addition, core losses for 2016 included higher operating and development costs and lower revenue and gross margin from the sale of solar systems at Edison Energy Group. Results during 2015 included income from Edison Capital's investments in affordable housing projects, which were sold at the end of 2015.
Consolidated non-core items for 2016 and 2015 for Edison International included:
•
SCE's 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.
•
Income of $20 million ($12 million after-tax) in 2015 at SCE 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.
•
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 represented the exit from this business activity.
•
Income of $5 million and $9 million for 2016 and 2015, respectively, related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method. Edison International reflected in core earnings the operating results of the solar projects, related financings and the priority return to the tax equity investor. The losses allocated to the tax equity investor under HLBV accounting method results in income allocated to subsidiaries of Edison International, neither of which is due to the operating 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 "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."
•
Income from discontinued operations, net of tax, was $12 million and $35 million for 2016 and 2015, respectively, primarily related to the resolution of tax issues related to EME. The discontinued operations from 2015 also reflects proceeds from insurance recoveries 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 2015 results to 2014.
Electricity Industry Trends
The electric power industry is undergoing transformative change driven by technological advancements such as customer-owned generation and energy storage, which could alter the nature of energy generation and delivery. California's environmental policy objectives are accelerating the pace and scope of the industry change. The electric grid is a critical enabler of the adoption of new energy technologies that support California's climate change and GHG reduction objectives, which continue to be publicly supported by California policy makers notwithstanding a potential change in the federal approach to such matters. The grid is also key to enabling more customer choices with respect to new energy technologies. The transformative change taking place in the electric power industry is integral to Edison International's strategy.
SCE plans to be a key enabler of the adoption of new energy technologies that benefit customers of the electric grid while also helping the state of California achieve its environmental goals. SCE expects to achieve these objectives through modernizing the electric grid to improve the safety and reliability of the transmission and distribution network and enabling increased penetration of DERs. SCE's ongoing focus to drive operational and service excellence should allow it to achieve these objectives while controlling costs and customer rates. SCE's focus on the transmission and distribution side of the utility business aligns with California's policy supporting competitive power markets. It also represents a lower risk than investment in conventional, natural gas-fired generation, which faces potentially stricter GHG limits as well as the increasing competitiveness of renewable resource fueled generation. For more information on the distribution grid development, see "—Capital Program—Distribution Grid Development" below.

4



Changes in the electric power industry are impacting customers and jurisdictions outside California as well. Edison International believes that other states will also pursue climate change and GHG reduction objectives, even if the federal approach to such objectives changes, and large commercial and industrial customers will continue to pursue cost reduction and sustainability goals. Edison Energy Group provides energy services to large commercial and industrial customers who may be impacted by these changes. Edison Energy Group seeks to provide advice in dealing with increasingly complex tariff and technology choices in order to support customers and their management of energy costs and risks.
Capital Program
Total capital expenditures (including accruals), were $3.5 billion in 2016. SCE's year-end rate base was $25.9 billion at December 31, 2016 compared to $24.6 billion at December 31, 2015.
To support a safe and reliable transmission and distribution network, and to modernize the electric grid to enable increased penetration of DERs, SCE forecasts capital expenditures of up to $19.3 billion for 2017 – 2020. The capital forecast for
2017 – 2020 reflects updates primarily to reflect the delay in receipt of project approvals on the West of Devers project and the Mesa Substation project (see "Liquidity—Capital Investment Plan" for further information). The forecasted CPUC capital expenditures include traditional capital spending, such as infrastructure replacement and maintenance, expansions and additions due to load growth and work requested by customers, as well as expenditures for grid modernization to support improved safety and reliability and increased levels of DERs. Traditional capital spending for 2017 reflects SCE's forecast capital expenditures for CPUC and FERC capital projects. Also included in 2017 capital expenditures is a baseline of grid modernization spending that will promote increased safety and reliability and also allow for a timely ramp-up of grid modernization capital expenditures in subsequent years. SCE has requested CPUC approval of a memorandum account to facilitate recovery in rates of such expenditures. The memorandum account has not yet been approved by the CPUC. SCE may receive further guidance on grid modernization spending from the CPUC as part of the DRP proceeding in the second half of 2017. Traditional capital expenditures for 2018 – 2020 reflect the amounts requested in the 2018 GRC filing and FERC capital projects. The CPUC has approved 81%, 89% and 92% of the traditional capital expenditures requested in the 2009, 2012 and 2015 GRC decisions, respectively. While SCE cannot predict the level of traditional capital spending that will be approved in the 2018 GRC decision, management is not aware of factors that would cause the percentage of SCE's request that is ultimately approved to be materially different from what has been approved in recent GRC decisions. SCE does not have prior approval experience with grid modernization capital expenditures and, therefore, is unable to predict an expected outcome.
Forecasted expenditures for FERC capital projects is subject to timely receipt of permitting, licensing and regulatory approvals. The following table sets forth a summary of capital expenditures for 2016 actual spend and a forecast for
2017 – 2020 on the basis described above:
(in millions)
 
2016 Actual
2017
2018
2019
2020
Total 2017 – 2020
Traditional capital expenditures
 
 
 
 
 
 
 
Distribution
 
$
2,840

$
3,145

$
3,214

$
3,156

$
3,085

$
12,600

Transmission
 
457

629

919

996

1,033

3,577

Generation
 
203

204

225

216

206

851

Total requested traditional capital expenditures1, 2
 
$
3,500

$
3,978

$
4,358

$
4,368

$
4,324

$
17,028

Grid modernization capital expenditures
 
$
27

$
182

$
637

$
751

$
714

$
2,284

Total capital expenditures
 
$
3,527

$
4,160

$
4,995

$
5,119

$
5,038

$
19,312

1
Includes Energy Storage of $50 million in 2016 and $60 million in the 2017 – 2020 period. Also, includes $12 million Charge Ready Pilot in 2017.
2 Capital expenditures for 2017 reflect management's expectations based on the 2015 GRC decision.
Capital expenditures for traditional capital projects under CPUC jurisdiction for 2017 are included in SCE's 2015 GRC. The 2018 – 2020 capital expenditures are included in the 2018 GRC application request discussed below. Recovery for
2017 – 2020 planned expenditures for traditional capital projects under FERC jurisdiction will be pursued through FERC-authorized mechanisms. For further information regarding the capital program, see "Liquidity and Capital Resources—SCE—Capital Investment Plan."

5


SCE's estimated weighted average annual rate base for 2017 – 2020 using the capital expenditures set forth in the table above is as follows:
(in millions)
 
2017
2018
2019
2020
Rate base for requested traditional capital expenditures
 
$
26,241

$
29,052

$
31,161

$
33,229

Rate base for requested grid modernization capital expenditures
 
—

279

802

1,398

Total rate base
 
$
26,241

$
29,331

$
31,963

$
34,627

The rate base above does not reflect reductions from the amounts requested in the 2018 GRC that may be included in a final decision.
Distribution Grid Development
Distribution Resources Plan
In July 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 climate change and GHG reduction targets, modernize the electric distribution system to accommodate two-way flows of energy associated with DERs, 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. The 2018 GRC includes operation and maintenance and capital expenditure requests consistent with SCE's DRP operation and maintenance and capital spending. Capital investments for 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 DER adoption, and other factors. In January 2016, the CPUC issued a scoping memo that provided for the issuance of guidance on utility spending to modify its grid in order to support its DRP. SCE expects to receive such guidance in the second half of 2017.
Charge Ready Program
In January 2016, the CPUC approved SCE's $22 million Charge Ready Phase 1 pilot program, which will allow SCE to install light-duty vehicle charging infrastructure, provide rebates to offset the cost of qualified customer-owned charging stations, and implement a supporting market education effort. Under the Phase 1 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. By the end of January 2017, SCE had executed agreements for 50 sites to deploy 776 charge ports. The results of this pilot will help shape Phase 2 of the program. SCE will file an application to obtain CPUC approval for Phase 2 after at least one year (Phase 1 launched in late May 2016) and 1,000 charge ports have been deployed.
Transportation Electrification Plan
In January 2017, SCE filed a transportation electrification plan with the CPUC that aims to accelerate the adoption of electric transportation, which is critical to California's climate change and GHG reduction objectives. The plan proposes a five-year program to fund medium- and heavy-duty vehicle charging infrastructure that follows the model developed for SCE's Charge Ready program discussed above. The proposal has an estimated five-year cost of $554 million ($532 million capital) in 2016 dollars. In addition, the plan proposes six pilot projects to be considered by the CPUC on an accelerated basis. The pilot projects would install charging infrastructure for electric transit buses and the Port of Long Beach; build clusters of fast charging sites in urban areas, and establish programs that would incentivize electric vehicle adoption. The estimated total cost of the six pilot projects is approximately $19 million ($14 million capital) in 2016 dollars. SCE expects to propose additional programs and pilots in the future.
All of the plan's proposed transportation electrification projects are subject to CPUC review and the timing and amount of capital investments for any approved project will depend upon implementation decisions, including scope and pace of adoption and GRC ratemaking decisions and other CPUC actions. SCE is unable to predict an expected outcome on or timing of implementation of any of the proposed projects. The capital costs for these proposed projects are not included in SCE's capital spending and rate base forecasts provided above.

6



Edison International Dividend Policy
In December 2016, Edison International declared a 13% increase to the annual dividend rate from $1.92 per share to $2.17 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. This is expected to yield a dividend growth at a faster pace than SCE's earnings growth.
Regulatory Proceedings
2018 General Rate Case
In September 2016, SCE filed its 2018 GRC application for the three-year period 2018 – 2020, which requested a 2018 revenue requirement of $5.885 billion, an increase of $222 million over the projected 2017 GRC authorized revenue requirement. In addition, SCE requested $48 million in one-time balancing and memorandum account recoveries. This represents a 2.7% increase over presently authorized total rates. SCE's 2018 GRC request also includes proposed revenue requirement increases of $533 million in 2019 and $570 million in 2020. For 2019 and 2020, respectively, these represent 4.2% and 5.2% increases over presently authorized total rates.
The capital programs requested in SCE's 2018 GRC are focused on safety and reliability through investments in the distribution grid to replace aging equipment and enhance capabilities to integrate increasing amounts of DERs. For further information, see "—Capital Program" above.
SCE's 2018 GRC request identifies areas of reduced operating cost to partially mitigate the customer rate impacts of the request.
SCE requested that the CPUC issue a final decision by the end of 2017. If the schedule for a final decision is delayed, SCE will request the CPUC to issue an order directing that the authorized revenue requirement changes be effective January 1, 2018. SCE cannot predict the revenue requirement the CPUC will ultimately authorize for 2018 through 2020 or forecast the timing of a final decision.
Permanent Retirement of San Onofre
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.
San Onofre CPUC Proceedings
In November 2014, the CPUC approved the San Onofre OII Settlement Agreement, which resolved the CPUC's investigation regarding the steam generator replacement project at San Onofre and the related outages and subsequent shutdown of San Onofre. Subsequently, the San Onofre OII proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned ALJ to consider whether, in light of the Company not reporting certain ex parte communications on a timely basis, the San Onofre OII Settlement Agreement remained reasonable, consistent with the law and in the public interest, which is the standard the CPUC applies in reviewing settlements submitted for approval. In comments filed with the CPUC in July 2016, SCE asserted that the Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the OII, however, have requested that the CPUC either modify the San Onofre OII Settlement Agreement or vacate its previous approval of the settlement and reinstate the OII for further proceedings.
In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ expressed concerns about the extent to which the failure to timely report ex parte communications had impacted the settlement negotiations and directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. The ruling set out a schedule requiring that at least two meet and confer sessions be held in the first quarter of 2017 and requiring the parties to submit a joint status report to the CPUC by April 28, 2017 if no modifications have been agreed to by some or all of the parties as a result of the meet and confer process. SCE has recorded a regulatory asset to reflect the expected recoveries under the San Onofre OII Settlement Agreement. At December 31, 2016, $857 million remains to be collected.
For more information on the challenges to the settlement of the San Onofre OII and the claims that SCE is pursuing against MHI, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."

7



Cost of Capital
On February 7, 2017, SCE, Pacific Gas and Electric Company, SDG&E, and SoCalGas (collectively, the “Investor-Owned Utilities”), ORA and TURN jointly filed a petition to modify the prior CPUC decisions addressing the Investor-Owned Utilities' costs of capital. The requested modifications would extend the next cost of capital application filing deadline two years to April 22, 2019 for the year 2020; reset SCE's authorized cost of long-term debt and preferred stock in 2018; and reduce SCE's authorized ROE. Subject to the CPUC's approval of the petition for modification, SCE's authorized ROE will be reduced from the current 10.45% to 10.30% beginning on January 1, 2018. The updated cost of capital and corresponding revenue requirement impact will be submitted to the CPUC in September 2017, to be effective January 1, 2018. While the actual changes to SCE's revenue requirement resulting from the petition for modification will not be known until SCE's filing in September 2017, SCE estimates that its annual revenue requirement will be reduced by approximately $66 million (approximately $39 million after-tax), beginning in 2018. Changes in market interest rates can have material effects on the cost of SCE’s future financings and consequently on the estimated change in annual revenue requirements.
The petition for modification provides that SCE's long-term debt, preferred stock and common equity costs will be reset for the year 2018 and will then remain unchanged until December 31, 2019 unless they are changed by the operation of the cost of capital adjustment mechanism. SCE’s current ratemaking capital structure (48% common equity, 43% long-term debt, and 9% preferred equity) will remain unchanged and the cost of capital adjustment mechanism would not operate in 2017 but could operate in 2018 to change the cost of capital for 2019. If the mechanism is activated for 2019, SCE’s new 10.30% ROE will be adjusted according to the existing terms of the mechanism.
Energy Efficiency Incentive Mechanism
In December 2016, the CPUC awarded SCE incentives of approximately $18 million, approximately 75% of the requested award, for Part 2 of the 2014 program year and Part 1 of the 2015 program year savings. There is no assurance that the CPUC will make an award for any given year.
FERC Formula Rates
In November 2016, SCE filed its 2017 annual update with the FERC with the rates effective from January 1, 2017 to December 31, 2017. The update provided support for an increase in SCE's transmission revenue requirement of $97 million or 9% over amounts currently authorized in rates. The increase is mainly due to the completion of several major transmission projects in 2015 and to recover prior undercollections. FERC has approved SCE's formula or methodology for setting transmission rates under its jurisdiction through 2017. SCE is required to file a replacement rate methodology by November 2017, to be effective January 2018.
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 were reported in connection with these events. SCE expects to incur penalties as a result of these events. Although resolution will be subject to settlement discussions with SED and CPUC review and approval, SCE has recorded a liability for the estimated loss.
RESULTS OF OPERATIONS
SCE
SCE's results of operations are derived mainly through two sources:
•
Earning activities – representing revenue authorized by the CPUC and FERC which is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investment in generation, transmission and distribution assets. The annual revenue requirements are comprised of authorized operation and maintenance costs, depreciation, taxes and a return consistent with the capital structure. Also, included in earnings activities are revenues or penalties related to incentive mechanisms, other operating revenue, and regulatory charges or disallowances.
•
Cost-recovery activities – representing CPUC- and FERC-authorized balancing accounts which allow for recovery of specific project or program costs, subject to reasonableness review or compliance with upfront standards. Cost-recovery activities include rates which provide recovery, subject to reasonableness review of, among other things, fuel costs, purchased power costs, public purpose related-program costs (including energy efficiency and demand-side management programs) and certain operation and maintenance expenses. SCE earns no return on these activities.

8



The following table is a summary of SCE's results of operations for the periods indicated.
 
2016
2015
2014
(in millions)
Earning
Activities
Cost-
Recovery
Activities
Total
Consolidated
Earning
Activities
Cost-
Recovery
Activities
Total Consolidated
Earning
Activities
Cost-
Recovery
Activities
Total Consolidated
Operating revenue
$
6,504

$
5,326

$
11,830

$
6,305

$
5,180

$
11,485

$
6,831

$
6,549

$
13,380

Purchased power and fuel
—

4,527

4,527

—

4,266

4,266

—

5,593

5,593

Operation and maintenance
1,939

798

2,737

1,977

913

2,890

2,106

951

3,057

Depreciation, decommissioning and amortization
1,998

—

1,998

1,915

—

1,915

1,720

—

1,720

Property and other taxes
351

—

351

334

—

334

318

—

318

Impairment and other charges
—

—

—

—

—

—

163

—

163

Total operating expenses
4,288

5,325

9,613

4,226

5,179

9,405

4,307

6,544

10,851

Operating income
2,216

1

2,217

2,079

1

2,080

2,524

5

2,529

Interest expense
(540
)
(1
)
(541
)
(525
)
(1
)
(526
)
(528
)
(5
)
(533
)
Other income and expenses
79

—

79

64

—

64

43

—

43

Income before income taxes
1,755

—

1,755

1,618

—

1,618

2,039

—

2,039

Income tax expense
256

—

256

507

—

507

474

—

474

Net income
1,499

—

1,499

1,111

—

1,111

1,565

—

1,565

Preferred and preference stock dividend requirements
123

—

123

113

—

113

112

—

112

Net income available for common stock
$
1,376

$
—

$
1,376

$
998

$
—

$
998

$
1,453

$
—

$
1,453

Net income available for common stock
 
 
$
1,376

 
 
$
998

 
 
$
1,453

Less: Non-core items
 
 
 
 
 
 
 
 
 
    Impairment and other charges
 
 
—

 
 
(382
)
 
 
(72
)
    NEIL insurance recoveries
 
 
—

 
 
12

 
 
—

Core earnings1
 
 
$
1,376

 
 
$
1,368

 
 
$
1,525

1 
See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results."
Earning Activities
2016 vs 2015
Earning activities were primarily affected by the following:
•
Higher operating revenue of $199 million is primarily due to:
•
An increase in revenue of approximately $191 million related to the increase in authorized revenue from the escalation mechanism set forth in the 2015 GRC decision.
•
An increase in FERC-related revenue of $68 million primarily related to higher operating costs including amortization of the regulatory asset associated with the Coolwater-Lugo transmission project and rate base growth partially offset by a $15 million increase in 2015 due to a change in estimate under the FERC formula rate mechanism.
•
An increase in revenue of $25 million ($15 million after-tax) related to the incremental return on the pole loading rate base recorded through the pole loading balancing account.
•
An increase of $46 million primarily due to tax benefits recognized in 2015 related to net operating loss carrybacks for San Onofre decommissioning costs resulting in a reduction in revenue in 2015 (offset in income taxes).
•
A decrease in revenue of $52 million for incremental tax benefits refunded to customers. In 2016, SCE recorded a revenue refund to customers of $133 million for 2012 – 2014 incremental tax benefits related to repair deductions (offset in income taxes as discussed below). This revenue refund resulted from the CPUC's approval of SCE's request to refund incremental tax repair deductions that were not addressed in SCE's 2015 GRC decision. Partially offsetting

9



the refund of 2012 – 2014 incremental tax repair deductions, SCE recognized $81 million lower incremental tax repairs and other benefits refunded to customers through balancing accounts in 2016.
•
Energy efficiency incentive awards were $18 million in 2016 compared to $29 million in 2015. In addition, in 2016, the CPUC approved a settlement agreement in which SCE agreed to refund $13 million related to incentive awards SCE received for savings achieved by its 2006 – 2008 energy efficiency programs.
•
SCE's portion of NEIL insurance and legal cost recoveries of approximately $20 million in 2015 arising from the outage and shutdown of the San Onofre Units 2 and 3 generating stations.
•
A decrease of $29 million for other operating revenue resulting from lower contributions received from customers due to the retroactive extension of bonus depreciation in the PATH Act of 2015.
•
Lower operation and maintenance expense of $38 million primarily due to lower labor related to SCE's focus on operational and service excellence as well as lower outside services partially offset by higher transmission and distribution costs for rain and storm-related activities.
•
Higher depreciation, decommissioning and amortization expense of $83 million primarily related to depreciation on higher rate base and amortization of the regulatory asset related to the Coolwater-Lugo plant, as discussed above.
•
Higher property and other taxes of $17 million primarily due to higher property assessed values in 2016.
•
Higher interest expense of $15 million primarily due to reduced interest capitalization (AFUDC debt) related to lower construction work in progress balances and a higher interest rate on balancing account overcollections in 2016.
•
Higher other income and expenses of $15 million primarily due to higher insurance benefits and lower advertising expense in 2016. See "Notes to Consolidated Financial Statements—Note 14. Interest and Other Income and Other Expenses" for further information.
•
Lower income taxes of $251 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.
•
Higher income tax benefits in 2016 of $31 million primarily due to $79 million related to the flow-through of incremental tax benefits for 2012 – 2014 to customers partially offset by lower income tax benefits in 2016 of
$48 million related to the flow-through of incremental tax repair and other benefits refunded to customers through balancing accounts.
•
Lower income tax expense in 2016 of $13 million related to the adoption of the FASB guidance on accounting for share-based payments (see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Guidance—New Accounting Guidance" for further information).
•
A change in liabilities related to uncertain tax positions related to repair deductions, which resulted in income tax benefits of $100 million during the second quarter of 2015. See "—Income Taxes" below for more information.
•
Higher pre-tax income in 2016, as discussed above.
•
Higher preferred and preference stock dividends of $10 million primarily related to new issuances in 2016 and late 2015 partially offset by redemptions of preferred stock.
2015 vs 2014
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

10



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.
•
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—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—Net 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 approximately $17 million related to not reporting certain ex parte communications on a timely basis.
•
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 of 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.
•
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.

11



•
Lower pre-tax income in 2015, as discussed above, partially offset by the impact of the San Onofre OII Settlement Agreement.
Cost-Recovery Activities
2016 vs 2015
Cost-recovery activities were primarily affected by the following:
•
Higher purchased power and fuel of $261 million primarily due to the NEIL insurance recoveries received in 2015 (discussed below) and a change in portfolio mix partially offset by lower load related to cooler weather.
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. SCE customer's portion of amounts recovered from NEIL has been distributed to SCE customers via a credit to SCE's ERRA account of approximately $300 million in 2015.
•
Lower operation and maintenance expense of $115 million primarily due to lower transmission access charges and lower spending on various public purpose programs partially offset by an increase in transmission and distribution costs for drought related activities.
2015 vs 2014
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.
Supplemental Operating Revenue Information
SCE's retail billed and unbilled revenue (excluding wholesale sales and balancing account over/undercollections) was
$10.7 billion in 2016 and $12.2 billion for both 2015 and 2014.
The 2016 revenue reflects:
•
A decrease of $1.15 billion primarily due to the implementations of the 2016 ERRA rate decrease and the 2015 GRC decision in January 2016.
•
A sales volume decrease of $321 million due to lower load requirements related to cooler weather experienced in 2016 compared to 2015.
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.
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").

12



Income Taxes
SCE’s income tax provision decreased by $251 million in 2016 compared to 2015 and increased by $33 million in 2015 compared to 2014. The effective tax rates were 14.6%, 31.3% and 23.2% for 2016, 2015 and 2014, respectively. SCE's effective tax rate is below the federal statutory rate of 35% primarily due to CPUC's ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences, which reverse over time. The accounting treatment for these temporary differences results in recording regulatory assets and liabilities for amounts that would otherwise be recorded to deferred income tax expense. The effective tax rate decrease in 2016 was primarily due to the
$382 million write-down in 2015 of regulatory assets (discussed in "Management Overview—Highlights of Operating Results") partially offset by revisions in liabilities related to uncertain tax positions in 2015. The effective tax rate increase in 2015 was primarily due to a $382 million write-down in 2015 of regulatory assets and income tax benefits in 2014 related to 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.
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" 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:
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
Edison Energy Group and subsidiaries1
$
(38
)
 
$
(6
)
 
$
(5
)
Edison Mission Group and subsidiaries
—

 
32

 
36

Corporate expenses and other2
(39
)
 
(39
)
 
(57
)
Total Edison International Parent and Other3 
$
(77
)
 
$
(13
)
 
$
(26
)
1   
Includes income of $5 million, $9 million and $2 million in 2016, 2015, 2014 related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method.
2   
Includes interest expense (pre-tax) of $37 million, $31 million and $25 million in 2016, 2015, and 2014, respectively.
3  
Includes income tax benefits of $15 million in 2016 related to the adoption of an accounting standard for share-based payments. See "Notes to Consolidated Financial Statements—Note 1" for further information.
The loss from continuing operations of Edison International Parent and Other increased $64 million in 2016 compared to 2015 primarily due to:
•
An increase in losses of Edison Energy Group of $32 million, including a $13 million after-tax charge during 2016 from a buy-out of an earn-out provision contained in one of the 2015 acquisitions, higher operating and development expenses and lower revenue and gross margin from the sale of solar systems in 2016 compared to 2015. The results for the twelve months ended December 31, 2016 include the three businesses acquired by Edison Energy in December 2015 and expanded sales and support personnel. Revenue for the Edison Energy Group was $42 million and $34 million for the twelve months ended December 31, 2016 and 2015, respectively.
•
A decrease in income from Edison Mission Group and subsidiaries of $32 million in 2016 primarily due to income related to affordable housing projects in 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.

13



The loss from continuing operations of Edison International Parent and Other decreased $13 million in 2015 compared to 2014 primarily due to:
•
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. For further information, see "Management Overview—Highlights of Operating Results."
•
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.
•
A decrease in the loss from corporate expenses and other primarily due to income tax benefits and lower corporate expenses during 2015.
Income from Discontinued Operations (Net of Tax)
Income from discontinued operations, net of tax, was $12 million, $35 million and $185 million for the years ended December 31, 2016, 2015 and 2014, respectively. The 2016 and 2015 income were primarily related to the resolution of tax issues related to EME. The 2015 income also included 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.
LIQUIDITY AND CAPITAL RESOURCES
SCE
SCE's ability to operate its business, fund capital expenditures, and implement its business strategy is dependent upon its cash flow and access to the bank and capital markets. SCE's overall cash flows fluctuate based on, among other things, its ability to recover its costs in a timely manner from its customers through regulated rates, changes in commodity prices and volumes, collateral requirements, interest obligations, dividend payments to Edison International, and the outcome of tax and regulatory matters.
In the next 12 months, SCE expects to fund its 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.
Available Liquidity
At December 31, 2016, SCE had $1.89 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, 2016, SCE's debt to total capitalization ratio was 0.43 to 1.
At December 31, 2016, SCE was in compliance with all other financial covenants that affect access to capital.

14



Capital Investment Plan
Major Transmission Projects
A summary of SCE's large transmission and substation projects during the next four years is presented below. The timing of the projects below is subject to timely receipt of permitting, licensing and regulatory approvals.
Project Name
Project Lifecycle Phase
Direct Expenditures (in millions)1
Inception to Date (in millions)1
Scheduled In-Service Date
West of Devers
Construction
$1,075
$58
2021
Mesa Substation
Construction
$608
$24
2020 – 2021
Alberhill System
Licensing
$397
$36
2021
Riverside Transmission Reliability
Licensing
$233
$5
2021
Eldorado-Lugo-Mohave Upgrade
Planning
$269
$5
2020
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 remaining investment.
West of Devers
The West of Devers Project consists of upgrading and reconfiguring approximately 48 miles of existing 220 kV transmission lines between the Devers, El Casco, Vista and San Bernardino substations, increasing the power transfer capabilities in support of California's renewable portfolio standards goals.
In August 2016, the CPUC approved the construction of the West of Devers Project. As a result of the delay in receipt of the Project's approval from the CPUC, SCE has deferred the timing of project capital expenditures. ORA filed an Application for Rehearing in September 2016 stating that the August 2016 decision failed to follow the California Environmental Quality Act when it approved the Project and should have approved the alternative project with the amended scope. SCE does not know when the CPUC will issue a decision on the Application for Rehearing. There is no stay of activities pending determination of the Application for Rehearing and SCE is continuing to perform activities related to construction, such as environmental permitting and mitigation planning in order to achieve a 2021 in-service date.
Mesa Substation
The Mesa Substation Project consists of demolishing the existing 220 kV Mesa Substation and constructing a new 500 kV substation. The Mesa 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. In February 2017, the CPUC issued a final decision approving SCE's proposed project. Construction planning activities that had been delayed pending the CPUC's final decision have commenced.
Alberhill System
The Alberhill System Project consists of constructing a new 500-kV substation, two 500-kV transmission lines to connect the proposed substation to the existing Serrano-Valley 500-kV transmission line, telecommunication equipment and subtransmission lines in unincorporated and incorporated portions of western Riverside County. The Project was designed to meet long-term forecasted electrical demand in the proposed Alberhill Project area and to increase electrical system reliability. In April 2016, the CPUC issued a draft environmental impact report that identified an alternative substation site. The $397 million estimated cost for this project reflects the scope proposed by SCE.
Riverside Transmission Reliability
The Riverside Transmission Reliability Project is a joint project between SCE and Riverside Public Utilities (RPU), the municipal utility department of the City of Riverside. While RPU would be responsible for constructing some of the Project's facilities within Riverside, SCE's portion of the Project consists of constructing upgrades to its system, including a new 230-kV Substation; certain interconnection and telecommunication facilities and transmission lines in the cities of Riverside, Jurupa Valley and Norco and in portions of unincorporated Riverside County. The purpose of the Project is to provide RPU and its customers with adequate transmission capacity to serve existing and projected load, to provide for long-term system capacity for load growth, and to provide needed system reliability. Due to changed circumstances since the time the Project

15



was originally developed, SCE informed the CPUC in July 2016 that it supports a revised description of the Project. The CPUC continues to collect information regarding the revised Project in support of a supplemental environmental review. Potential revisions to the Project have not been reflected in the direct expenditures or scheduled in service date in the table above, however, revisions are likely to increase the total direct expenditures and delay the completion of the Project.
Eldorado-Lugo-Mohave Upgrade
The Eldorado-Lugo-Mohave Upgrade Project will increase capacity on existing transmission lines to allow additional renewable energy to flow from Nevada to southern California. The Project would modify SCE’s existing Eldorado, Lugo, and Mohave electrical substations to accommodate the increased current flow from Nevada to southern California; increase the power flow through the existing 500 kV transmission lines by constructing two new capacitors along the lines; raise transmission tower heights to meet ground clearance requirements; and install communication wire on our transmission lines to allow for communication between existing SCE substations.
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. Segments 4-11 were placed in service in December 2016.
SCE filed a petition for modification with the CPUC in January 2017 to update the cost estimate for all elements of segments 4-11 to $2.7 billion (2016 dollars) from $2.0 billion (2016 dollars) of CPUC-approved cost findings. The cost increase is based on several factors, including additional project scope, schedule delays and work stoppages due to regulatory activity, increased environmental activities, and higher costs than the historical data used for estimates. Many of the cost increases are due to external factors not contemplated when the initial cost estimates were developed and not accounted for in the CPUC's original cost findings, which had also reduced the amount of contingency significantly below SCE's original estimates. Cost recovery for nearly all transmission elements of the project is incorporated in the existing FERC rates, subject to FERC review and approval.
Coolwater-Lugo
In February 2016, SCE filed an abandoned plant recovery request at FERC for the costs of the cancelled Coolwater-Lugo transmission project pursuant to the authority granted by FERC for SCE to recover 100% of all prudently-incurred costs if the project is cancelled for reasons beyond SCE's control. The project was cancelled by the CPUC in 2015 due to a reduction in need. SCE requested recovery of the $37.1 million in costs that SCE incurred for the project over a twelve-month period through the FERC transmission formula rate. In December 2016, SCE reached a settlement under which it will recover 100% of the requested $37.1 million of costs incurred in return for certain additional procedural safeguards to be implemented in all future abandoned plant recovery requests. The period for parties to file any protests to the settlement has expired without any protests filed but the settlement remains subject to FERC approval.
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. Decommissioning of San Onofre Unit 1 began in 1999 and major decommissioning work was completed in 2008, except for reactor vessel disposal and certain underground work that was deferred to allow for the construction of the San Onofre Independent Spent Fuel Storage Installation. The initial activity phase of radiological decommissioning of Units 2 and 3 began in June 2013 with SCE filing a certification of permanent cessation of power operations at San Onofre with the NRC. SCE is currently permitted to start major radiological decommissioning activities pursuant to NRC regulations, provided SCE obtains all necessary environmental permits for decommissioning. SCE has engaged a decommissioning general contractor to undertake a significant scope of decommissioning activities for Units 1, 2 and 3 at San Onofre.
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—Nuclear Decommissioning and Asset

16



Retirement Obligations." The CPUC will conduct a reasonableness review for costs for each year. SCE's share of the decommissioning costs recorded during 2016 were $168 million and are subject to reasonableness review by the CPUC.
SCE has nuclear decommissioning trust funds for San Onofre Units 2 and 3 of $2.8 billion as of December 31, 2016. 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.
SCE Dividends
SCE made $701 million and $758 million in dividend payments to its parent, Edison International, in 2016 and 2015, respectively. The timing and amount of future dividends 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, 2016, 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, 2016.
(in millions)
 
 
Collateral posted as of December 31, 20161
 
$
91

Incremental collateral requirements for power procurement contracts resulting from a potential downgrade of SCE's credit rating to below investment grade
 
37

Incremental collateral requirements for power procurement contracts resulting from adverse market price movement2
 
3

Posted and potential collateral requirements
 
$
131

1 
Net collateral provided to counterparties and other brokers consisted $93 million in letters of credit and surety bonds and $2 million of cash reflected in "Other current liabilities" on the consolidated balance sheets.
2 
Incremental collateral requirements were based on potential changes in SCE's forward positions as of December 31, 2016 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, 2016, SCE had regulatory balancing account net overcollections of $1.7 billion, primarily consisting of overcollections related to the base rate revenue 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 2017. 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.

17



Edison International Parent and Other
Edison International Parent and Other's liquidity and its ability to pay operating expenses and pay dividends to common shareholders are dependent on dividends from SCE, realization of tax benefits and access to bank and capital markets. Edison International may also finance working capital requirements, payment of obligations and capital investments, including capital contributions to subsidiaries to fund new businesses, with commercial paper or other borrowings, subject to availability in the capital markets.
At December 31, 2016, Edison International Parent had $712 million available under its $1.25 billion multi-year revolving credit facility. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
The debt covenant in Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio as defined in the credit agreement of less than or equal to 0.65 to 1. At December 31, 2016, Edison International Parent's consolidated debt to total capitalization ratio was 0.47 to 1.
At December 31, 2016, Edison International Parent was in compliance with all financial covenants that affect access to capital.
Net Operating Loss and Tax Credit Carryforwards
Edison International has approximately $1,152 million of net operating loss and tax credit carryforwards at December 31, 2016 (excluding $176 million of unrecognized tax benefits and $242 million of Capistrano Wind net operating loss and tax credit carryforwards) which are available to offset future consolidated taxable income or tax liabilities (see Note 7 for further information on taxes payable to Capistrano Wind). 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 tax benefits has been deferred (currently forecasted to be realized through 2021). The timing of realization of these tax benefits may be further delayed in the event of other changes in tax regulations and the value of the net operating loss carryforwards could be permanently reduced if tax reform decreases the corporate tax rate.
Edison Energy Group Capital Expenditures
Forecasted capital expenditures for Edison Energy Group's commercial solar activities are estimated to be $114 million in 2017. Edison Energy Group expects to finance a majority of these expenditures through project debt and tax equity financings. For further information, see "Notes to Consolidated Financial Statements—Note 9. Investments."
Historical Cash Flows
SCE
(in millions)
2016
 
2015
 
2014
Net cash provided by operating activities
$
3,523

 
$
4,624

 
$
3,660

Net cash (used in) provided by financing activities
(219
)
 
(812
)
 
181

Net cash used in investing activities
(3,291
)
 
(3,824
)
 
(3,857
)
Net increase (decrease) in cash and cash equivalents
$
13

 
$
(12
)
 
$
(16
)

18



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 2016, 2015 and 2014.
 
Years ended December 31,
 
Change in cash flows
(in millions)
2016
2015
2014
 
2016/2015
2015/2014
Net income
$
1,499

$
1,111

$
1,565

 

 
Non cash items1
2,108

2,231

2,381

 
 
 
    Subtotal
$
3,607

$
3,342

$
3,946

 
$
265

$
(604
)
Changes in cash flow resulting from working capital2
236

16

79

 
220

(63
)
Derivative assets and liabilities, net
13

45

(40
)
 
(32
)
85

Regulatory assets and liabilities, net
(292
)
1,729

(358
)
 
(2,021
)
2,087

Other noncurrent assets and liabilities, net3
(41
)
(508
)
33

 
467

(541
)
Net cash provided by operating activities
$
3,523

$
4,624

$
3,660

 
$
(1,101
)
$
964

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 nuclear decommissioning trusts.
Net cash provided by operating activities was impacted by the following:
Net income and noncash items increased in 2016 by $265 million from 2015 and decreased in 2015 by $604 million from 2014. The increase in 2016 was primarily due to higher authorized revenue in 2016 from the escalation mechanism set forth in the 2015 GRC decision. The decrease in 2015 was primarily due to the implementation of the 2015 GRC decision. The factors that impacted these items are discussed under "Results of Operations—SCE—Earning Activities."
Net cash for working capital was $236 million, $16 million and $79 million in 2016, 2015 and 2014, respectively. The net cash for 2016 and 2015 was primarily related to timing of disbursements ($45 million in 2016 and $120 million in 2015) and timing of receipts from customers ($230 million in 2016 and $70 million in 2015). In addition, SCE had net tax payments of $78 million in 2016 and $144 million in 2015. The net cash in 2014 was primarily related to net tax refunds of $88 million due to net operating loss carrybacks to periods that SCE previously had taxable income.
Net cash provided by regulatory assets and liabilities, including changes in over (under) collections of balancing accounts, was $(292) million, $1.7 billion and $(358) million in 2016, 2015 and 2014, respectively. SCE has a number of balancing accounts, which impact cash flows based on differences between timing of collection of amounts through rates and accrual expenditures. Cash flows were primarily impacted by the following:
2016
•
Lower cash due to a decrease in ERRA overcollections for fuel and purchased power of $419 million in 2016 primarily due to the implementation of the 2016 ERRA rate decrease in January 2016, partially offset by lower than forecasted power and gas prices experienced in 2016.
•
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 increased by $309 million in 2016 due to higher funding and lower spending for these programs.
•
SCE had a decrease in cash of approximately $182 million primarily due to a 2016 refund of 2015 overcollections resulting from the implementation of the 2015 GRC decision which was authorized to be refunded to customers over a two year period.

19



2015
•
Higher cash due to a decrease in ERRA undercollections of $1.5 billion in 2015 primarily due to lower power and gas prices experienced in 2015, the 2015 application of 2013 and 2014 nuclear decommissioning costs refunds against ERRA undercollections and the NEIL settlement proceeds from insurance claims arising out of the failures of the San Onofre replacement steam generators. In January 2015, SCE reclassified the regulatory liability for generator settlements to ERRA to refund customers as required by the CPUC.
•
During 2015, BRRBA overcollections increased by $314 million primarily due to revenue previously collected from customers that was expected to be refunded as part of the 2015 GRC decision.
•
Overcollections for the public purpose and energy efficiency programs decreased by $191 million in 2015 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.
•
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).
2014
•
During 2014, BRRBA overcollections decreased by $242 million primarily due to refunds to customers of approximately $150 million, related to the sale of Four Corners, an electric generating facility in which SCE held a 48% ownership interest, in December 2013.
•
Overcollections for the public purpose and energy efficiency programs decreased by $278 million in 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 2014.
•
During 2014, ERRA undercollections increased by $23 million primarily due to the amount and price of power and fuel being higher than forecasted. The increase was partially offset by a $540 million reclassification 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.
Cash flows (used in) provided by other noncurrent assets and liabilities were $(41) million, $(508) million and $33 million in 2016, 2015 and 2014, respectively. Major factors affecting cash flow related to noncurrent assets and liabilities were activities related to SCE's nuclear decommissioning trusts (principally related to the payment of decommissioning costs). Decommissioning costs of San Onofre were approximately $168 million and $216 million in 2016 and 2015, respectively (such costs were recorded as a reduction of SCE's asset retirement obligation).

20



Net Cash (Used in) Provided by Financing Activities
The following table summarizes cash provided by financing activities for 2016, 2015 and 2014. 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)
2016
 
2015
 
2014
Issuances of first and refunding mortgage bonds, net
$
—

 
$
1,287

 
$
498

Issuances of pollution control bonds, net and other
—

 
126

 
—

Long-term debt matured or repurchased
(217
)
 
(761
)
 
(607
)
Short-term debt financing, net
719

 
(619
)
 
490

Issuances of preference stock, net
294

 
319

 
269

Payments of common stock dividends to Edison International
(701
)
 
(758
)
 
(378
)
Redemptions of preference stock
(125
)
 
(325
)
 
—

Payments of preferred and preference stock dividends
(123
)
 
(116
)
 
(111
)
Other
(66
)
 
35

 
20

Net cash (used in) provided by financing activities
$
(219
)
 
$
(812
)
 
$
181

Net Cash Used in Investing Activities
Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Capital expenditures were $3.6 billion for 2016, $4.2 billion for 2015 and $3.9 billion for 2014, primarily related to transmission, distribution and generation investments. The decrease in capital expenditures during 2016 was primarily due to lower FERC capital spending. Net proceeds (purchases) of nuclear decommissioning trust investments were $179 million, $374 million and $(44) million for 2016, 2015 and 2014, respectively. See "Nuclear Decommissioning Trusts" below for further discussion. The 2016 net proceeds from sale of nuclear decommissioning trust investments was used to fund decommissioning costs less net earnings during the period. The 2015 net proceeds from sale of nuclear decommissioning trust investments was used to fund 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 addition, during the third quarter of 2016, SCE received proceeds of $140 million for a loan on the cash surrender value of life insurance policies. The proceeds were used for general corporate purposes.
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)
2016
 
2015
 
2014
Net cash (used in) provided by operating activities:
   Nuclear decommissioning trusts
$
(179
)
 
$
(428
)
 
$
39

Net cash flow from investing activities:
   Proceeds from sale of investments
3,212

 
3,506

 
2,617

   Purchases of investments
(3,033
)
 
(3,132
)
 
(2,661
)
Net cash impact
$
—

 
$
(54
)
 
$
(5
)
Net cash (used in) provided by 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. Beginning in March 2016, funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information.

21



Edison International Parent and Other
The table below sets forth condensed historical cash flow from operations for Edison International Parent and Other.
(in millions)
2016
 
2015
 
2014
Net cash used in operating activities
$
(267
)
 
$
(115
)
 
$
(412
)
Net cash provided by financing activities
314

 
224

 
464

Net cash used in investing activities
(125
)
 
(68
)
 
(50
)
Net (decrease) increase in cash and cash equivalents
$
(78
)
 
$
41

 
$
2

Net Cash Used in Operating Activities
Net cash used in operating activities increased in 2016 by $152 million from 2015 and decreased in 2015 by $297 million from 2014 due to:
•
$214 million, $204 million and $225 million of cash payments made to the Reorganization Trust in September 2016, September 2015 and April 2014, respectively, related to the EME Settlement Agreement. 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.
•
$21 million outflow in June 2016 related to the buy-out of an earn-out provision with the former shareholders of a company acquired by Edison Energy in 2015. See "Results of Operations—Edison International Parent and Other—Loss from Continuing Operations" for further information.
•
$32 million cash outflow from operating activities in 2016, compared to $54 million cash inflow in 2015 and $2 million cash outflow in 2014, due to timing of payments and receipts relating to interest and operating costs.
Net Cash Provided by Financing Activities
Net cash provided by financing activities were as follows:
(in millions)
 
2016
 
2015
 
2014
Dividends paid to Edison International common shareholders
 
$
(626
)
 
$
(544
)
 
$
(463
)
Dividends received from SCE
 
701

 
758

 
378

Payment for stock-based compensation
 
(110
)
 
(119
)
 
(106
)
Receipt from stock option exercises
 
59

 
67

 
66

Long-term debt issuance, net
 
397

 
7

 
(4
)
Short-term debt financing, net
 
(108
)
 
47

 
589

Other
 
1

 
8

 
4

Net cash provided by financing activities
 
$
314

 
$
224

 
$
464

Net Cash Used in Investing Activities
Net cash used in investing activities relates to Edison Energy Group's capital expenditures primarily for commercial solar installations ($101 million in 2016, $15 million in 2015 and $49 million in 2014). In addition, the cash outflow in 2015 was due to the acquisitions of three companies for approximately $100 million to support Edison Energy Group's commercial and industrial services growth strategy. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information.

22


Contractual Obligations and Contingencies
Contractual Obligations
Edison International Parent and Other and SCE's contractual obligations as of December 31, 2016, for the years 2017 through 2021 and thereafter are estimated below.
(in millions)
Total
 
Less than
1 year
 
1 to 3 years
 
3 to 5 years
 
More than
5 years
SCE:
 
 
 
 
 
 
 
 
 
Long-term debt maturities and interest1
$
18,801

 
$
1,044

 
$
1,442

 
$
1,509

 
$
14,806

Power purchase agreements:2
 
 
 
 
 
 
 
 
 
Renewable energy contracts
31,199

 
1,516

 
3,310

 
3,562

 
22,811

Qualifying facility contracts
530

 
187

 
235

 
55

 
53

Other power purchase agreements
4,039

 
769

 
1,120

 
892

 
1,258

Other operating lease obligations3
443

 
52

 
83

 
50

 
258

Purchase obligations:4
 
 
 
 
 
 
 
 
 
Other contractual obligations
1,211

 
156

 
244

 
180

 
631

Total SCE5,6,7
56,223

 
3,724

 
6,434

 
6,248

 
39,817

Edison International Parent and Other:
 
 
 
 
 
 
 
 
 
Long-term debt maturities and interest1
925

 
426

 
32

 
28

 
439

Total Edison International Parent and Other5
925

 
426

 
32

 
28

 
439

Total Edison International6,7
$
57,148

 
$
4,150

 
$
6,466

 
$
6,276

 
$
40,256

1 
For additional details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements." Amount includes interest payments totaling $8.36 billion and $93 million over applicable period of the debt for SCE and Edison International Parent and Other, respectively.
2 
Certain power purchase agreements entered into with independent power producers are treated as operating or capital leases. For further discussion, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies."
3 
At December 31, 2016, 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, 2016, other commitments were primarily related to maintaining reliability and expanding SCE's transmission and distribution system and capacity reduction contracts.
5 
At December 31, 2016, Edison International Parent and Other and SCE had estimated contributions to the pension and PBOP plans. SCE estimated contributions are $106 million, $106 million, $115 million, $157 million and $160 million in 2017, 2018, 2019, 2020 and 2021, respectively, which are excluded from the table above. Edison International Parent and Other estimated contributions are $51 million, $18 million, $28 million, $26 million and $26 million for the same respective periods and are excluded from the table above. These amounts represent estimates that are based on assumptions that are subject to change. See "Notes to Consolidated Financial Statements—Note 8. Compensation and Benefit Plans" for further information.
6 
At December 31, 2016, Edison International and SCE had a total net liability recorded for uncertain tax positions of $471 million and $371 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" and "—Note 9. Investments," 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
For a discussion of SCE's environmental remediation liabilities, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Environmental Remediation."
Off-Balance Sheet Arrangements
SCE has variable interests in power purchase contracts with variable interest entities and a variable interest in unconsolidated Trust I, Trust II, Trust III, Trust IV and Trust V 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%, $325 million (aggregate liquidation preference) of 5.375% and $300 million (aggregate liquidation preference) of 5.45%, 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."
MARKET RISK EXPOSURES
Edison International's and SCE's primary market risks include fluctuations in interest rates, commodity prices and volumes, and counterparty credit. Derivative instruments are used to manage market risks including market risks of SCE's customers. For 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, and to fund business operations and 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" 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, 2016, if the market interest rates were changed while leaving all other assumptions the same:
(in millions)
Carrying Value
 
Fair Value
 
10% Increase
 
10% Decrease
Edison International
$
11,156

 
$
12,368

 
$
11,892

 
$
12,876

SCE
10,333

 
11,539

 
11,070

 
12,040

Commodity Price Risk
SCE and its customers are exposed to the risk of a change in the market price of natural gas, electric power and transmission congestion. SCE's hedging program is designed to reduce exposure to variability in market prices related to SCE's purchases and sales of electric power and natural gas. SCE expects recovery of its related hedging costs through the ERRA balancing account or CPUC-approved procurement plans, and as a result, exposure to commodity price is not expected to impact earnings, but may impact timing of cash flows. As part of this program, SCE enters into energy options, swaps, forward 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."

24



The fair value of outstanding derivative instruments used to mitigate exposure to commodity price risk was a net liability of $1.1 billion and $1.2 billion at December 31, 2016 and 2015, 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, 2016, if the electricity prices or gas prices were changed while leaving all other assumptions constant:
(in millions)
December 31, 2016

Increase in electricity prices by 10%
$
112

Decrease in electricity prices by 10%
(92
)
Increase in gas prices by 10%
(36
)
Decrease in gas prices by 10%
43

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 credit ratings using published 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, 2016, the amount of balance sheet exposure as described above broken down by the credit ratings of SCE's counterparties, was as follows:
 
December 31, 2016
(in millions)
Exposure2
 
Collateral
 
Net Exposure
S&P Credit Rating1
 
 
 
 
 
A or higher
$
74

 
$
(3
)
 
$
71

1 
SCE assigns a credit rating based on the lower of a counterparty's S&P, Fitch or Moody's Investors Service rating. For ease of reference, the above table uses the S&P classifications to summarize risk, but reflects the lower of the three 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.

25



In November 2014, the CPUC approved the San Onofre OII Settlement Agreement, which resolved the CPUC's investigation regarding the steam generator replacement project at San Onofre and the related outages and subsequent shutdown of San Onofre. In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ expressed concerns about the extent to which the failure to timely report ex parte communications had impacted the settlement negotiations and directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement.
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.
Key Assumptions and Approach Used.    SCE's management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to SCE or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. Using these factors, management has determined that existing regulatory assets and liabilities are probable of future recovery or settlement. This determination reflects the current regulatory climate and is subject to change in the future. SCE's judgment that the San Onofre Regulatory Asset recorded at December 31, 2016 is probable, though not certain, of recovery is based on SCE's knowledge of the facts and judgment in applying the relevant regulatory principles to the issue. Such judgment is subject to uncertainty, and regulatory principles and precedents are not necessarily binding and are capable of interpretation. SCE has recorded a regulatory asset to reflect the expected recoveries under the San Onofre OII Settlement Agreement. At
December 31, 2016, $857 million remains to be collected.
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, 2016, the consolidated balance sheets included regulatory assets of $7.8 billion and regulatory liabilities of $6.5 billion. If different judgments were reached on recovery of costs and timing of income recognition, SCE's earnings may vary from the amounts reported.
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.

26



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 2013 for Palo Verde and in 2014 for San Onofre Units 1, 2 and 3. See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" for further discussion of the plans for decommissioning of San Onofre. SCE estimates that it will spend approximately $6.3 billion through 2079 to decommission its nuclear facilities. San Onofre Units 1, 2 and 3 decommissioning cost estimates are updated in each Nuclear Decommissioning Triennial Proceeding. Palo Verde decommissioning cost estimates are updated every three years by the operating agent, Arizona Public Services.
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, "material, equipment and other," and low-level radioactive waste costs are included in each of the NRC decommissioning stages; license termination, site restoration, and spent fuel storage.
•
Escalation Rates. Annual escalation rates are used to convert the decommissioning cost estimates in base year dollars to decommissioning cost estimates in future-year dollars. Escalation rates are primarily used for labor, material, equipment, and low level radioactive waste burial costs. SCE's current estimates are based upon SCE's decommissioning cost methodology used for ratemaking purposes. Average escalation rates range from 1.7% to 7.5% (depending on the cost element) annually.
•
Timing. Cost estimates for Palo Verde are based on an assumption that decommissioning will commence promptly after the current NRC operating licenses expire. The Palo Verde 1, 2, 3 operating licenses currently expire in 2045, 2046 and 2047 respectively. San Onofre Unit 1 started decommissioning in 1998 and Units 2 and 3 began in 2013. Cost estimates for San Onofre Units are currently based on completion of decommissioning activities by 2052.
•
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 2051 and 2075, respectively. Costs for spent fuel monitoring are included until 2051 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 $2.5 billion as of December 31, 2016, based on decommissioning studies performed in 2013 for Palo Verde and in 2014 for San Onofre Units 1, 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. The ARO for decommissioning San Onofre Units 2 & 3 is expected to be updated after onboarding the decommissioning general contractor and the subsequent development of a new decommissioning cost estimate during 2017.
The following table illustrates the increase to the ARO liability if the cost escalation rate was adjusted while leaving all other assumptions constant:
(in millions)
Increase to ARO and
Regulatory Asset at
December 31, 2016
Uniform increase in escalation rate of 1 percentage point
$
481

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.

27



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, 2016, Edison International's and SCE's pension plans had a $4.3 billion and $3.8 billion benefit obligation, respectively, and total 2016 expense for these plans was $101 million and $93 million, respectively. As of December 31, 2016, the benefit obligation for both Edison International's and SCE's PBOP plans were $2.3 billion, and total 2016 expense for Edison International's and SCE's plans was $20 million and $19 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.
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, 2016, this cumulative difference amounted to a regulatory asset of $95 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 2016:
(in millions)
Pension
Plans
Postretirement
Benefits Other
than Pensions
Discount rate1
4.18
%
4.55
%
Expected long-term return on plan assets2
7.00
%
5.60
%
Assumed health care cost trend rates3
*

7.50
%
* 
Not applicable to pension plans.
1 
The discount rate enables Edison International and SCE to state expected future cash flows at a present value on the measurement date. Edison International and SCE select its discount rate by performing a yield curve analysis. This analysis determines the equivalent discount rate on projected cash flows, 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 5.6% 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 8.5%, 9.7% and 5.8% for the one-year, five-year and ten-year periods ended December 31, 2016, respectively. Actual time-weighted, annualized returns on the PBOP plan assets were 7.0%, 9.5% and 5.0% 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 2022 and beyond.

28



As of December 31, 2016, Edison International and SCE had unrecognized pension costs of $666 million and $598 million, and unrecognized PBOP costs of $140 million and $136 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, $479 million of SCE's pension costs and $33 million of SCE's PBOP costs are recorded as regulatory assets and is expected to be recovered over the average expected future service of employees.
Edison International's and SCE's pension and PBOP plans are subject to limits established for federal tax deductibility. SCE funds its pension and PBOP plans in accordance with amounts allowed by the CPUC. Executive pension plans have no plan assets.
Effect if Different Assumptions Used.    Changes in the estimated costs or timing of pension and other postretirement benefit obligations, or the assumptions and judgments used by management underlying these estimates, could have a material effect on the recorded expenses and liabilities.
The following table summarizes the increase or (decrease) to projected benefit obligation for pension and the accumulated benefit obligation for PBOP if the discount rate were changed while leaving all other assumptions constant:
 
Edison International
 
SCE
(in millions)
Increase in discount rate by 1%
 
Decrease in discount rate by 1%
 
Increase in discount rate by 1%
 
Decrease in discount rate by 1%
Change to projected benefit obligation for pension
$
(422
)
 
$
513

 
$
(365
)
 
$
444

Change to accumulated benefit obligation for PBOP
(319
)
 
372

 
(318
)
 
370

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 $31 million and $29 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 $20 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:
 
Edison International
 
SCE
(in millions)
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
$
244

 
$
(200
)
 
$
243

 
$
(199
)
Change to annual aggregate service and interest costs
11

 
(9
)
 
11

 
(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."

29



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, ability to borrow funds, 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 electricity 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. 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.
The Edison International consolidated tax group retains significant net operating loss and tax credit carryforwards.  Realization of such tax benefits may be delayed or permanently reduced by future tax legislation that extends bonus depreciation or reduces the current corporate tax rate.
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, through Edison Energy Group, is developing competitive businesses that are diversified geographically, these businesses are not material. As a result, Edison International's future performance may be affected by events and economic factors unique to California or by regional regulation or legislation.
Edison International is developing businesses held by Edison Energy Group that may not be successful.
Edison International, through Edison Energy Group, is developing businesses to capitalize on changes in the electricity industry. Edison International intends to invest in companies to develop the capabilities of the Edison Energy Group entities but there can be no assurance that these entities will be profitable.
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 and other local, state and federal agencies.
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 opponents and such delay or defeat could have a material effect on SCE's business.

30



In September 2016, the California Governor signed into law several CPUC reform bills that establish rules governing, among other subjects, 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 its costs from its customers, including the costs of electricity purchased for its customers, through the rates it charges its customers as approved by the CPUC and FERC. SCE's financial results also depend on its ability to earn a reasonable return on capital, including long-term debt and equity. SCE's ability to recover its costs and earn a reasonable rate of return can be affected by many factors, including the time lag between when costs are incurred and when those costs are recovered in customers' rates and differences between the forecast or authorized costs embedded in rates (which are set on a prospective basis) and the amount of actual costs incurred. The CPUC or the FERC may not allow SCE to recover costs on the basis that such costs were not reasonably or prudently incurred or for other reasons. Further, SCE may be required to incur expenses before the relevant regulatory agency approves the recovery of such costs. For example, the recovery of the Tehachapi transmission project costs are subject to FERC approval and the public need for the project is reviewed by the CPUC. SCE filed a petition for modification with the CPUC in January 2017 to update the cost estimate for all elements of segments 4-11 to $2.7 billion (2016 dollars) from $2.0 billion (2016 dollars) of CPUC-approved cost findings. For further information, see "Liquidity and Capital Resources—SCE—Capital Investment Plan—Tehachapi" 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 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 Proceedings—2018 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 have increased due to the closure of the 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.

31



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, 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
California utilities are experiencing increasing deployment by customers and third parties of DERs, such as solar generation, energy storage, energy efficiency and demand response technologies. This growth will require modernization of the electric distribution grid to, among other things, accommodate two-way flows of electricity and increase the grid's capacity to interconnect DERs. To this end, the CPUC is conducting proceedings to: evaluate changes to the planning and operation of the electric distribution grid in order to prepare for higher penetration of DERs; consider future grid modernization and grid reinforcement investments; evaluate if traditional grid investments can be deferred by DERs, and if feasible, what, if any, compensation to utilities would be appropriate; and clarify the role of the electric distribution grid operator. The outcome of these proceedings is unknown. These changes could materially affect SCE's business model and its financial condition and results of operations. For more information, see "Management Overview—Capital Program—Distribution Grid Development" in the MD&A.
Customer-owned generation and community choice aggregators each reduce the amount of electricity customers purchase from utilities and have the effect of increasing utility rates unless customer rates are designed to allocate the costs of the distribution grid across all customers that benefit from its use. For example, 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 result in increased utility rates for those customers who do not own their generation. Such increases influence the public discussion regarding changes in the electric utility business model.
In addition, the FERC has opened transmission development to competition from independent developers, allowing such developers to compete with incumbent utilities for the construction and operation of transmission facilities. For more information, see "Business—SCE—Competition."
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 operational risks and the need for superior execution in SCE's activities. SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage these risks as well as the risks inherent in operating and maintaining its facilities, the operation of which can be hazardous. SCE's inherent operating risks include such matters as the risks of human performance, workforce capabilities, 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.

32



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. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. The CPUC has increased its focus on public safety with an emphasis on heightened compliance with construction and operating standards and the potential for penalties being imposed on utilities. Additionally, the CPUC has delegated to its staff the authority to issue citations to electric utilities, which can impose fines of up to $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.
There are inherent risks associated with owning and decommissioning nuclear power generating facilities and obtaining cost reimbursement, including, among other things, costs exceeding estimates, execution risks, 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. SCE believes that the nuclear decommissioning trusts' assets will be sufficient to pay the estimated costs of decommissioning without further contributions but the costs ultimately incurred could exceed the current estimates. The costs of decommissioning San Onofre are subject to reasonableness reviews by the CPUC. These costs may not be recoverable through regulatory processes or otherwise unless SCE can establish that the costs were reasonably incurred. In addition, SCE faces inherent execution risks including such matters as the risks of human performance, workforce capabilities, public opposition, permitting delays, and governmental approvals.
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 $13.4 billion. SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available of $450 million per site. If nuclear incident liability claims were to exceed $450 million, the remaining amount would be made up from contributions of approximately $13.0 billion made by all of the nuclear facility owners in the U.S., up to an aggregate total of $13.4 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 $450 million. If this public liability limit of $13.4 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. Edison International, SCE or its contractors may experience coverage reductions and/or increased wildfire insurance costs in future years. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. 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. For more information on wildfire insurance risk, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—Wildfire Insurance."

33



Cybersecurity and Physical Security 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.
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 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. Environmental regulations and permitting requirements also affect the cost and timing of transmission and distribution projects. At the state level, the current trend is toward more stringent standards, stricter regulation, higher reductions of GHG emissions, 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 customer rates. 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. Current and future California laws and regulations also increase the required amount of energy that must be procured from renewable resources. 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


34



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, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the index 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, 2016, 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 21, 2017




35



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 as of December 31, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the index 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 financial 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 21, 2017































36


















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37



Consolidated Statements of Income
Edison International
 


 
 
 
Years ended December 31,
(in millions, except per-share amounts)
2016
 
2015
 
2014
Total operating revenue
$
11,869

 
$
11,524

 
$
13,413

Purchased power and fuel
4,527

 
4,266

 
5,593

Operation and maintenance
2,868

 
2,990

 
3,149

Depreciation, decommissioning and amortization
2,007

 
1,919

 
1,720

Property and other taxes
354

 
336

 
322

Impairment and other charges
21

 
5

 
157

Total operating expenses
9,777

 
9,516

 
10,941

Operating income
2,092

 
2,008

 
2,472

Interest and other income
123

 
174

 
147

Interest expense
(581
)
 
(555
)
 
(560
)
Other expenses
(44
)
 
(59
)
 
(80
)
Income from continuing operations before income taxes
1,590

 
1,568

 
1,979

Income tax expense
177

 
486

 
443

Income from continuing operations
1,413

 
1,082

 
1,536

Income from discontinued operations, net of tax
12

 
35

 
185

Net income
1,425

 
1,117

 
1,721

Preferred and preference stock dividend requirements of utility
123

 
113

 
112

Other noncontrolling interests
(9
)
 
(16
)
 
(3
)
Net income attributable to Edison International common shareholders
$
1,311

 
$
1,020

 
$
1,612

Amounts attributable to Edison International common shareholders:
 
 
 
 
 
Income from continuing operations, net of tax
$
1,299

 
$
985

 
$
1,427

Income from discontinued operations, net of tax
12

 
35

 
185

Net income attributable to Edison International common shareholders
$
1,311

 
$
1,020

 
$
1,612

Basic earnings per common share attributable to Edison International common shareholders:
 
 
 
 
 
Weighted-average shares of common stock outstanding
326

 
326

 
326

Continuing operations
$
3.99

 
$
3.02

 
$
4.38

Discontinued operations
0.03

 
0.11

 
0.57

Total
$
4.02

 
$
3.13

 
$
4.95

Diluted earnings per common share attributable to Edison International common shareholders:
 
 
 
 
 
Weighted-average shares of common stock outstanding, including effect of dilutive securities
330

 
329

 
329

Continuing operations
$
3.94

 
$
2.99

 
$
4.33

Discontinued operations
0.03

 
0.11

 
0.56

Total
$
3.97

 
$
3.10

 
$
4.89

Dividends declared per common share
$
1.9825

 
$
1.7325

 
$
1.4825


The accompanying notes are an integral part of these consolidated financial statements.
38


Consolidated Statements of Comprehensive Income
 
Edison International
 
 
 
 
 
 
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Net income
 
$
1,425

 
$
1,117

 
$
1,721

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
 
2

 
1

 
(47
)
Prior service cost arising during the period plus amortization included in net income
 
—

 
1

 
—

Other
 
1

 
—

 
2

Other comprehensive income (loss), net of tax
 
3

 
2

 
(45
)
Comprehensive income
 
1,428

 
1,119

 
1,676

Less: Comprehensive income attributable to noncontrolling interests
 
114

 
97

 
109

Comprehensive income attributable to Edison International
 
$
1,314

 
$
1,022

 
$
1,567





The accompanying notes are an integral part of these consolidated financial statements.
39


Consolidated Balance Sheets
 
Edison International
 
 
 
 
 
 
 
 
December 31,
(in millions)
 
2016
 
2015
ASSETS
 
 
 
 
Cash and cash equivalents
 
$
96

 
$
161

Receivables, less allowances of $62 for uncollectible accounts at both dates
 
714

 
771

Accrued unbilled revenue
 
370

 
565

Inventory
 
239

 
267

Derivative assets
 
73

 
79

Regulatory assets
 
350

 
560

Other current assets
 
281

 
251

Total current assets
 
2,123

 
2,654

Nuclear decommissioning trusts
 
4,242

 
4,331

Other investments
 
83

 
203

Total investments
 
4,325

 
4,534

Utility property, plant and equipment, less accumulated depreciation and amortization of $9,000 and $8,548 at respective dates
 
36,806

 
34,945

Nonutility property, plant and equipment, less accumulated depreciation of $99 and $85 at respective dates
 
194

 
140

Total property, plant and equipment
 
37,000

 
35,085

Derivative assets
 
1

 
84

Regulatory assets
 
7,455

 
7,512

Other long-term assets
 
415

 
360

Total long-term assets
 
7,871

 
7,956

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total assets
 
$
51,319

 
$
50,229



The accompanying notes are an integral part of these consolidated financial statements.
40


Consolidated Balance Sheets
 
Edison International
 
 
 
 
 
 
 
 
December 31,
(in millions, except share amounts)
 
2016
 
2015
LIABILITIES AND EQUITY
 
 
 
 
Short-term debt
 
$
1,307

 
$
695

Current portion of long-term debt
 
981

 
295

Accounts payable
 
1,342

 
1,310

Accrued taxes
 
50

 
72

Customer deposits
 
269

 
242

Derivative liabilities
 
216

 
218

Regulatory liabilities
 
756

 
1,128

Other current liabilities
 
991

 
967

Total current liabilities
 
5,912

 
4,927

Long-term debt
 
10,175

 
10,883

Deferred income taxes and credits
 
8,327

 
7,480

Derivative liabilities
 
941

 
1,100

Pensions and benefits
 
1,354

 
1,759

Asset retirement obligations
 
2,590

 
2,764

Regulatory liabilities
 
5,726

 
5,676

Other deferred credits and other long-term liabilities
 
2,102

 
2,246

Total deferred credits and other liabilities
 
21,040

 
21,025

Total liabilities
 
37,127

 
36,835

Commitments and contingencies (Note 11)
 

 

Redeemable noncontrolling interest
 
5

 
6

Common stock, no par value (800,000,000 shares authorized; 325,811,206 shares issued and outstanding at respective dates)
 
2,505

 
2,484

Accumulated other comprehensive loss
 
(53
)
 
(56
)
Retained earnings
 
9,544

 
8,940

Total Edison International's common shareholders' equity
 
11,996

 
11,368

Noncontrolling interests – preferred and preference stock of utility
 
2,191

 
2,020

Total equity
 
14,187

 
13,388

 
 
 
 
 
 
 
 
 
 
Total liabilities and equity
 
$
51,319

 
$
50,229



The accompanying notes are an integral part of these consolidated financial statements.
41


Consolidated Statements of Cash Flows
 
Edison International
 
 
 
 
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Cash flows from operating activities:
 
 
 
 
 
 
Net income
 
$
1,425

 
$
1,117

 
$
1,721

Less: Income from discontinued operations
 
12

 
35

 
185

Income from continuing operations
 
1,413

 
1,082

 
1,536

Adjustments to reconcile to net cash provided by operating activities:
 
 
 
 
 
 
Depreciation, decommissioning and amortization
 
2,098

 
2,005

 
1,815

Allowance for equity during construction
 
(74
)
 
(87
)
 
(65
)
Impairment and other charges
 
—

 
5

 
157

Deferred income taxes and investment tax credits
 
190

 
449

 
522

Other
 
20

 
(28
)
 
20

Nuclear decommissioning trusts
 
(179
)
 
(428
)
 
39

EME settlement payments, net of insurance proceeds
 
(209
)
 
(176
)
 
(225
)
Changes in operating assets and liabilities:
 
 
 
 
 
 
Receivables
 
52

 
49

 
64

Inventory
 
8

 
14

 
(25
)
Accounts payable
 
35

 
8

 
14

Prepaid and accrued taxes
 
(6
)
 
(28
)
 
(100
)
Other current assets and liabilities
 
211

 
(24
)
 
(103
)
Derivative assets and liabilities, net
 
13

 
45

 
(40
)
Regulatory assets and liabilities, net
 
(292
)
 
1,729

 
(358
)
Other noncurrent assets and liabilities
 
(24
)
 
(106
)
 
(3
)
Net cash provided by operating activities
 
3,256

 
4,509

 
3,248

Cash flows from financing activities:
 
 
 
 
 
 
Long-term debt issued or remarketed, net of discount and issuance costs of $7, $17, and $6 at respective periods
 
397

 
1,420

 
494

Long-term debt matured or repurchased
 
(220
)
 
(762
)
 
(607
)
Preference stock issued, net
 
294

 
319

 
269

Preference stock redeemed
 
(125
)
 
(325
)
 
—

Short-term debt financing, net
 
611

 
(572
)
 
1,079

Dividends to noncontrolling interests
 
(123
)
 
(116
)
 
(111
)
Dividends paid
 
(626
)
 
(544
)
 
(463
)
Other
 
(113
)
 
(8
)
 
(16
)
Net cash provided by (used in) financing activities
 
95

 
(588
)
 
645

Cash flows from investing activities:
 
 
 
 
 
 
Capital expenditures
 
(3,734
)
 
(4,225
)
 
(3,906
)
Proceeds from sale of nuclear decommissioning trust investments
 
3,212

 
3,506

 
2,617

Purchases of nuclear decommissioning trust investments
 
(3,033
)
 
(3,132
)
 
(2,661
)
Life insurance policy loans proceeds
 
140

 
—

 
—

Other
 
(1
)
 
(41
)
 
43

Net cash used in investing activities
 
(3,416
)
 
(3,892
)
 
(3,907
)
Net (decrease) increase in cash and cash equivalents
 
(65
)
 
29

 
(14
)
Cash and cash equivalents at beginning of year
 
161

 
132

 
146

Cash and cash equivalents at end of year
 
$
96

 
$
161

 
$
132


The accompanying notes are an integral part of these consolidated financial statements.
42


Consolidated Statements of Changes in Equity
 
 
 
 
 
 
Edison International
 
 
 
 
 
 
 
 
 
Equity Attributable to Common Shareholders
 
 
Noncontrolling Interests
 
 
(in millions)
Common
Stock
 
Accumulated
Other
Comprehensive
Loss
 
Retained
Earnings
 
Subtotal
 
 
Preferred
and
Preference
Stock
 
Total
Equity
Balance at December 31, 2013
$
2,403

 
$
(13
)
 
$
7,548

 
$
9,938

 
 
$
1,753

 
$
11,691

Net income
—

 
—

 
1,612

 
1,612

 
 
112

 
1,724

Other comprehensive loss
—

 
(45
)
 
—

 
(45
)
 
 
—

 
(45
)
Common stock dividends declared ($1.4825 per share)
—

 
—

 
(483
)
 
(483
)
 
 
—

 
(483
)
Dividends and distributions to noncontrolling interests and other
—

 
—

 
—

 
—

 
 
(112
)
 
(112
)
Stock-based compensation and other
15

 
—

 
(104
)
 
(89
)
 
 
—

 
(89
)
Noncash stock-based compensation and other
27

 
—

 
—

 
27

 
 
—

 
27

Issuance of preference stock
—

 
—

 
—

 
—

 
 
269

 
269

Balance at December 31, 2014
$
2,445

 
$
(58
)
 
$
8,573

 
$
10,960

 
 
$
2,022

 
$
12,982

Net income
—

 
—

 
1,020

 
1,020

 
 
113

 
1,133

Other comprehensive income
—

 
2

 
—

 
2

 
 
—

 
2

Common stock dividends declared ($1.7325 per share)
—

 
—

 
(564
)
 
(564
)
 
 
—

 
(564
)
Dividends and distributions to noncontrolling interests and other
—

 
—

 
—

 
—

 
 
(113
)
 
(113
)
Stock-based compensation and other
15

 
—

 
(85
)
 
(70
)
 
 
—

 
(70
)
Noncash stock-based compensation and other
24

 
—

 
—

 
24

 
 
—

 
24

Issuance of preference stock
—

 
—

 
—

 
—

 
 
319

 
319

Redemption of preference stock
—

 
—

 
(4
)
 
(4
)
 
 
(321
)
 
(325
)
Balance at December 31, 2015
$
2,484

 
$
(56
)
 
$
8,940

 
$
11,368

 
 
$
2,020

 
$
13,388

Net income
—

 
—

 
1,311

 
1,311

 
 
123

 
1,434

Other comprehensive income
—

 
3

 
—

 
3

 
 
—

 
3

Common stock dividends declared ($1.9825 per share)
—

 
—

 
(646
)
 
(646
)
 
 
—

 
(646
)
Dividends and distributions to noncontrolling interests and other
—

 
—

 
—

 
—

 
 
(123
)
 
(123
)
Stock-based compensation and other
(1
)
 
—

 
(59
)
 
(60
)
 
 
—

 
(60
)
Noncash stock-based compensation and other
22

 
—

 
—

 
22

 
 
—

 
22

Issuance of preference stock
—

 
—

 
—

 
—

 
 
294

 
294

Redemption of preference stock
—

 
—

 
(2
)
 
(2
)
 
 
(123
)
 
(125
)
Balance at December 31, 2016
$
2,505

 
$
(53
)
 
$
9,544

 
$
11,996

 
 
$
2,191

 
$
14,187


The accompanying notes are an integral part of these consolidated financial statements.
43



















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44



Consolidated Statements of Income
Southern California Edison Company

 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Operating revenue
 
$
11,830

 
$
11,485

 
$
13,380

Purchased power and fuel
 
4,527

 
4,266

 
5,593

Operation and maintenance
 
2,737

 
2,890

 
3,057

Depreciation, decommissioning and amortization
 
1,998

 
1,915

 
1,720

Property and other taxes
 
351

 
334

 
318

Impairment and other charges
 
—

 
—

 
163

Total operating expenses
 
9,613

 
9,405

 
10,851

Operating income
 
2,217

 
2,080

 
2,529

Interest and other income
 
123

 
123

 
122

Interest expense
 
(541
)
 
(526
)
 
(533
)
Other expenses
 
(44
)
 
(59
)
 
(79
)
Income before income taxes
 
1,755

 
1,618

 
2,039

Income tax expense
 
256

 
507

 
474

Net income
 
1,499

 
1,111

 
1,565

Less: Preferred and preference stock dividend requirements
 
123

 
113

 
112

Net income available for common stock
 
$
1,376

 
$
998

 
$
1,453


Consolidated Statements of Comprehensive Income
 
 
 
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Net income
 
$
1,499

 
$
1,111

 
$
1,565

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
 
1

 
5

 
(19
)
Prior service cost arising during the period plus amortization included in net income
 
—

 
1

 
—

Other
 
1

 
—

 
2

Other comprehensive income (loss), net of tax
 
2

 
6

 
(17
)
Comprehensive income
 
$
1,501

 
$
1,117

 
$
1,548




The accompanying notes are an integral part of these consolidated financial statements.
45


Consolidated Balance Sheets
Southern California Edison Company

 
 
December 31,
(in millions)
 
2016
 
2015
ASSETS
 
 
 
 
Cash and cash equivalents
 
$
39

 
$
26

Receivables, less allowances of $61 and $62 for uncollectible accounts at respective dates
 
699

 
724

Accrued unbilled revenue
 
369

 
564

Inventory
 
239

 
256

Derivative assets
 
73

 
79

Regulatory assets
 
350

 
560

Other current assets
 
262

 
234

Total current assets
 
2,031

 
2,443

Nuclear decommissioning trusts
 
4,242

 
4,331

Other investments
 
50

 
168

Total investments
 
4,292

 
4,499

Utility property, plant and equipment, less accumulated depreciation of $9,000 and $8,548 at respective dates
 
36,806

 
34,945

Nonutility property, plant and equipment, less accumulated depreciation of $89 and $81 at respective dates
 
75

 
73

Total property, plant and equipment
 
36,881

 
35,018

Derivative assets
 
1

 
84

Regulatory assets
 
7,455

 
7,512

Other long-term assets
 
231

 
239

Total long-term assets
 
7,687

 
7,835

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total assets
 
$
50,891

 
$
49,795


The accompanying notes are an integral part of these consolidated financial statements.
46


Consolidated Balance Sheets
Southern California Edison Company

 
 
December 31,
(in millions, except share amounts)
 
2016
 
2015
LIABILITIES AND EQUITY
 
 
 
 
Short-term debt
 
$
769

 
$
49

Current portion of long-term debt
 
579

 
79

Accounts payable
 
1,344

 
1,299

Accrued taxes
 
45

 
46

Customer deposits
 
269

 
242

Derivative liabilities
 
216

 
218

Regulatory liabilities
 
756

 
1,128

Other current liabilities
 
729

 
760

Total current liabilities
 
4,707

 
3,821

Long-term debt
 
9,754

 
10,460

Deferred income taxes and credits
 
9,886

 
9,073

Derivative liabilities
 
941

 
1,100

Pensions and benefits
 
896

 
1,284

Asset retirement obligations
 
2,586

 
2,762

Regulatory liabilities
 
5,726

 
5,676

Other deferred credits and other long-term liabilities
 
1,912

 
1,947

Total deferred credits and other liabilities
 
21,947

 
21,842

Total liabilities
 
36,408

 
36,123

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)
 
2,168

 
2,168

Additional paid-in capital
 
657

 
652

Accumulated other comprehensive loss
 
(20
)
 
(22
)
Retained earnings
 
9,433

 
8,804

Total common shareholder's equity
 
12,238

 
11,602

Preferred and preference stock
 
2,245

 
2,070

Total equity
 
14,483

 
13,672

Total liabilities and equity
 
$
50,891

 
$
49,795



The accompanying notes are an integral part of these consolidated financial statements.
47


Consolidated Statements of Cash Flows
 
Southern California Edison Company
 
 
 
 
 

Years ended December 31,
(in millions)

2016

2015

2014
Cash flows from operating activities:

 

 

 
Net income

$
1,499


$
1,111


$
1,565

Adjustments to reconcile to net cash provided by operating activities:

 

 

 
Depreciation, decommissioning and amortization

2,085


1,996


1,810

Allowance for equity during construction

(74
)

(87
)

(65
)
Impairment and other charges

—


—


163

Deferred income taxes and investment tax credits

88


308


462

  Other

9


14


11

Nuclear decommissioning trusts
 
(179
)
 
(428
)
 
39

Changes in operating assets and liabilities:

 

 

 
Receivables

25


25


64

Inventory

(3
)

19


(19
)
Accounts payable

45


30


12

Prepaid and accrued taxes

(16
)

(16
)

129

Other current assets and liabilities

185


(42
)

(107
)
Derivative assets and liabilities, net

13


45


(40
)
Regulatory assets and liabilities, net

(292
)

1,729


(358
)
Other noncurrent assets and liabilities

138


(80
)

(6
)
Net cash provided by operating activities

3,523


4,624


3,660

Cash flows from financing activities:

 

 

 
Long-term debt issued or remarketed, net of discount and issuance costs of $17 and $2 for the years ended 2015 and 2014

—


1,413


498

Long-term debt matured or repurchased

(217
)

(761
)

(607
)
Preferred stock issued, net

294


319


269

Preference stock redeemed

(125
)

(325
)

—

Short-term debt financing, net

719


(619
)

490

Dividends paid

(824
)

(874
)

(489
)
Other
 
(66
)
 
35

 
20

Net cash (used in) provided by financing activities

(219
)

(812
)

181

Cash flows from investing activities:

 

 

 
Capital expenditures

(3,633
)

(4,210
)

(3,857
)
Proceeds from sale of nuclear decommissioning trust investments

3,212


3,506


2,617

Purchases of nuclear decommissioning trust investments

(3,033
)

(3,132
)

(2,661
)
Life insurance policy loans proceeds

140


—


—

Other

23


12


44

Net cash used in investing activities

(3,291
)

(3,824
)

(3,857
)
Net increase (decrease) in cash and cash equivalents

13


(12
)

(16
)
Cash and cash equivalents, beginning of year

26


38


54

Cash and cash equivalents, end of year

$
39


$
26


$
38



The accompanying notes are an integral part of these consolidated financial statements.
48


Consolidated Statements of Changes in Equity
Southern California Edison Company
 
Equity Attributable to Edison International
 
 
 
 
(in millions)
Common
Stock
 
Additional
Paid-in
Capital
 
Accumulated
Other
Comprehensive
Loss
 
Retained
Earnings
 
Preferred
and
Preference
Stock
 
Total
Equity
Balance at December 31, 2013
$
2,168

 
$
592

 
$
(11
)
 
$
7,594

 
$
1,795

 
$
12,138

Net income
—

 
—

 
—

 
1,565

 
—

 
1,565

Other comprehensive loss
—

 
—

 
(17
)
 
—

 
—

 
(17
)
Dividends declared on common stock
—

 
—

 
—

 
(525
)
 
—

 
(525
)
Dividends declared on preferred and preference stock
—

 
—

 
—

 
(112
)
 
—

 
(112
)
Stock-based compensation 
—

 
20

 
—

 
(64
)
 
—

 
(44
)
Noncash stock-based compensation
—

 
12

 
—

 
(4
)
 
—

 
8

Issuance of preference stock
—

 
(6
)
 
—

 
—

 
275

 
269

Balance at December 31, 2014
$
2,168

 
$
618

 
$
(28
)
 
$
8,454

 
$
2,070

 
$
13,282

Net income
—

 
—

 
—

 
1,111

 
—

 
1,111

Other comprehensive income
—

 
—

 
6

 
—

 
—

 
6

Dividends declared on common stock
—

 
—

 
—

 
(611
)
 
—

 
(611
)
Dividends declared on preferred and preference stock
—

 
—

 
—

 
(113
)
 
—

 
(113
)
Stock-based compensation
—

 
23

 
—

 
(33
)
 
—

 
(10
)
Noncash stock-based compensation
—

 
13

 
—

 
—

 
—

 
13

Issuance of preference stock
—

 
(6
)
 
—

 
—

 
325

 
319

Redemption of preference stock
—

 
4

 
—

 
(4
)
 
(325
)
 
(325
)
Balance at December 31, 2015
$
2,168

 
$
652

 
$
(22
)
 
$
8,804

 
$
2,070

 
$
13,672

Net income
—

 
—

 
—

 
1,499

 
—

 
1,499

Other comprehensive income
—

 
—

 
2

 
—

 
—

 
2

Dividends declared on common stock
—

 
—

 
—

 
(701
)
 
—

 
(701
)
Dividends declared on preferred and preference stock
—

 
—

 
—

 
(123
)
 
—

 
(123
)
Stock-based compensation
—

 
—

 
—

 
(44
)
 
—

 
(44
)
Noncash stock-based compensation
—

 
9

 
—

 
—

 
—

 
9

Issuance of preference stock
—

 
(6
)
 
—

 
—

 
300

 
294

Redemption of preference stock
—

 
2

 
—

 
(2
)
 
(125
)
 
(125
)
Balance at December 31, 2016
$
2,168

 
$
657

 
$
(20
)
 
$
9,433

 
$
2,245

 
$
14,483





The accompanying notes are an integral part of these consolidated financial statements.
49


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 holding company for subsidiaries engaged in pursuing competitive business opportunities across energy services and distributed solar for commercial and industrial customers. Such 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.
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:
 
Edison International
 
SCE
 
December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Money market funds
$
41

 
$
37

 
$
18

 
$
8

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)
2016
 
2015
 
2016
 
2015
Book balances reclassified to accounts payable
$
138

 
$
162

 
$
136

 
$
158


50



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
SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at average cost.
Emission Allowances
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 $113 million and $79 million at December 31, 2016 and 2015, respectively. GHG emission obligations were $95 million and $86 million at December 31, 2016 and 2015, respectively and are classified as "Other current liabilities" on the consolidated balance sheets.
Property, Plant and Equipment
SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, pension and benefits, and property taxes are capitalized as part of plant additions. 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:
 
Estimated Useful Lives
Weighted-Average
Useful Lives
Generation plant
10 years to 57 years
38 years
Distribution plant
20 years to 60 years
43 years
Transmission plant
40 years to 65 years
53 years
General plant and other
5 years to 60 years
22 years
Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. Depreciation expense was $1.52 billion, $1.42 billion and $1.33 billion for 2016, 2015 and 2014, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.8%, 3.9% and 4.0% for 2016, 2015 and 2014, respectively. Replaced or retired property costs are charged to accumulated depreciation.
Nuclear fuel for the Palo Verde Nuclear Power Plant ("Palo Verde") is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. 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 $74 million, $87 million and $65 million in 2016, 2015 and 2014, respectively, and is reflected in "Interest and other income." AFUDC debt was $23 million, $31 million and $25 million in 2016, 2015 and 2014, respectively and is reflected as a reduction of "Interest expense."
Major Maintenance
Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred.
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

51



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.
In 2014, the CPUC approved the San Onofre OII Settlement Agreement that SCE had entered into with a number of intervening parties. The San Onofre OII Settlement Agreement had resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the related outages and subsequent shutdown of San Onofre. In 2014, SCE had recorded a pre-tax impairment charge of approximately $163 million (approximately $72 million after-tax). Including amounts previously recorded as an impairment charge 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).
In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. See Note 11 for further information.
Goodwill
Edison International assesses goodwill through annual goodwill impairment tests, at the reporting unit level, as of October 1st of each year. The fair value of the Edison Energy and SoCore Energy reporting units exceeded their carrying values at the date of the annual impairment analysis. As of December 31, 2016, goodwill is comprised of $78 million at the Edison Energy reporting unit and $22 million at the SoCore Energy reporting unit. Edison International will update these tests between annual tests if events occur or circumstances change such that it is more likely than not that the fair value of a reporting unit is below its carrying value.
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.
SCE has not recorded an asset retirement obligation for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities.
The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde:
 
December 31,
(in millions)
2016
 
2015
Beginning balance
$
2,762

 
$
2,819

Accretion1
157

 
173

Revisions
(165
)
 
(14
)
Liabilities settled
(168
)
 
(216
)
Ending balance
$
2,586

 
$
2,762

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.

52



The recorded liability to decommission SCE's nuclear power facilities (included in the table above) is $2.5 billion as of December 31, 2016. In 2016, SCE updated the recorded liability for Palo Verde and San Onofre Unit 1 based on the 2013 decommissioning study performed for Palo Verde and the 2014 study for San Onofre Unit 1. The recorded liability for San Onofre Unit 2 and 3 is based on a 2014 decommissioning study which followed the decision to permanently retire San Onofre. The 2015 NDTCP filing is expected to be updated for San Onofre Units 2 and 3 after onboarding the decommissioning general contractor and the subsequent development of a new decommissioning cost estimate during 2017.
Decommissioning costs, which are recovered through customer rates over the term of each nuclear facility's operating license, are recorded as a component of depreciation expense, with a corresponding credit to the ARO regulatory liability. 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.
Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $6.3 billion through 2079 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 1.7% to 7.5% (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 2.4% to 4.1%. Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts. If the assumed return on trust assets is not earned or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates. See Note 9 for further information.
Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceeding. SCE's nuclear decommissioning trust investments primarily consist of fixed income 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.
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 $184 million and $201 million at December 31, 2016 and 2015, respectively, reflected as long-term "Regulatory assets" in the consolidated balance sheets. Edison International and SCE had unamortized debt issuance costs of $10 million and $7 million at December 31, 2016, respectively, and $11 million and $7 million at December 31, 2015, respectively, reflected in "Other long-term assets" on the consolidated balance sheets. In addition, Edison International and SCE had debt issuance costs of $81 million and $71 million at December 31, 2016, respectively, and $81 million and $77 million at December 31, 2015, respectively, reflected as a reduction of "Long-term debt" on the consolidated balance sheets.
Amortization of deferred financing costs charged to interest expense is as follows:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Amortization of deferred financing costs charged to interest expense
$
31

 
$
33

 
$
36

 
$
27

 
$
28

 
$
32


53



Revenue Recognition
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 $111 million, $138 million and $134 million in 2016, 2015 and 2014, respectively. When SCE acts as an agent, the taxes are accounted for on a net basis. Amounts billed to and collected from customers for these taxes are remitted to the taxing authorities and are not recognized as electric utility revenue.
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, 2016 and 2015. 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. 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.
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. 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. Most of SCE's qualifying facilities ("QFs") 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. 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.

54



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 deliver such shares for the settlement of option exercises, performance shares, deferred stock units and restricted stock units. Performance shares awarded in 2014 that are earned are settled half in cash and half in common stock, while the performance shares awarded in 2016 and 2015 that are earned are settled solely in cash. Deferred stock units and 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. Under new accounting guidance adopted in 2016, share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created.
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, 2016, SCE's 13-month weighted-average common equity component of total capitalization was 50.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $585 million, resulting in a restriction on net assets of approximately $13.9 billion.

55



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:
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
Basic earnings per share – continuing operations:
 
 
 
 
 
Income from continuing operations attributable to common shareholders
$
1,299

 
$
985

 
$
1,427

Participating securities dividends
—

 
(1
)
 
(1
)
Income from continuing operations available to common shareholders
$
1,299

 
$
984

 
$
1,426

Weighted average common shares outstanding
326

 
326

 
326

Basic earnings per share – continuing operations
$
3.99

 
$
3.02

 
$
4.38

Diluted earnings per share – continuing operations:
 
 
 
 
 
Income from continuing operations attributable to common shareholders
$
1,299

 
$
985

 
$
1,427

Participating securities dividends
—

 
(1
)
 
(1
)
Income from continuing operations available to common shareholders
$
1,299

 
$
984

 
$
1,426

Income impact of assumed conversions
1

 
1

 
1

Income from continuing operations available to common shareholders and assumed conversions
$
1,300

 
$
985

 
$
1,427

Weighted average common shares outstanding
326

 
326

 
326

Incremental shares from assumed conversions
4

 
3

 
3

Adjusted weighted average shares – diluted
330

 
329

 
329

Diluted earnings per share – continuing operations
$
3.94

 
$
2.99

 
$
4.33

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 167,795, 2,046,045 and 125,345 shares of common stock for the years ended December 31, 2016, 2015 and 2014, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.
Income Taxes
Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets. Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. 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.
Interest income, interest expense and penalties associated with income taxes are reflected in "Income tax expense" on the consolidated statements of income.
Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its subsidiaries. Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis.

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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 noncontrolling equity investors (referred to as tax equity investors) which are entitled to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary over time. These entities are 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 consolidated assets and liabilities of these entities were $74 million and $23 million, respectively, at December 31, 2016 and were $82 million and $32 million, respectively, at December 31, 2015. Income (loss) of these entities are 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 investors' 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 ($9 million and $16 million in 2016 and 2015, respectively).
New Accounting Guidance
Accounting Guidance Adopted
In April 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct reduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At December 31, 2016, the amount of debt issuance costs that are reflected as a reduction of "Long-term debt" was $71 million for SCE and $81 million for Edison International. At December 31, 2015, the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a reduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International.
In April 2015, the FASB issued an accounting standards 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 adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements.
In May 2015, the FASB issued an accounting standards update which removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using net asset value per share or its equivalent as a practical expedient. Edison International and SCE adopted in the fourth quarter of 2016. Certain prior year amounts have been retrospectively adjusted.
In March 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Under this new guidance, the tax effects related to share based payments are recorded through the income statement. Previously, tax benefits in excess of compensation cost ("windfalls") were recorded in equity, and tax deficiencies ("shortfalls") were recorded in equity to the extent of previous windfalls, and then to the income statement. In addition, as part of this new guidance an entity recognizes excess tax benefits regardless of whether the benefit reduces taxes payable in the current period, subject to normal valuation allowance considerations. Edison International and SCE adopted this guidance in the fourth quarter of 2016 using the modified retrospective approach, effective January 1, 2016. As a result, all excess tax benefits resulting from 2016 stock option exercises were reflected in the income statement. Income tax expense for Edison International and SCE was reduced by approximately $28 million and $13 million, respectively, for the year ended December 31, 2016. In addition, Edison International and SCE recorded an increase to beginning retained earnings for pre-2016 stock option exercises that had not been previously recorded in equity ($42 million and $6 million for Edison International and SCE, respectively). On a prospective basis, the excess tax benefits are classified as an operating activity along with other income tax cash flows on the statement of cash flows. Accruals of compensation costs are based on the number of awards that are expected to vest. Edison International and SCE made an accounting policy election to continue to estimate the number of awards that are expected to vest rather than account for forfeitures when they occur.


57



Accounting Guidance Not Yet Adopted
In May 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016. 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. This standard will be adopted on January 1, 2018. Edison International and SCE have completed the preliminary phases of their assessment of the impact on the consolidated financial statements and do not believe the adoption of this standard will have a material impact on the results of operations. Edison International and SCE anticipate adopting the standard using the modified retrospective application which means that Edison International and SCE would recognize the cumulative effect of initially applying the revenue standard as an adjustment to the opening balance of retained earnings in 2018.
In January 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. 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.
In February 2016, the FASB issued an accounting standards update related to lease accounting including enhanced disclosures. Under the new standard, a lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. Lessees will need to recognize leases on the balance sheet as a right-of-use asset and a related lease liability, and classify the leases as either operating or finance. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. Operating leases will result in straight-line expense while finance leases will result in a higher initial expense pattern due to the interest component. SCE, as a regulated entity, is permitted to continue to have straight-line expense for finance leases, assuming the rate recovery is based upon current payments. Lessees can elect to exclude from the balance sheet short-term contracts one year or less. This guidance is effective January 1, 2019. Early adoption is permitted, but Edison International and SCE do not expect to elect early adoption. The adoption of this standard is expected to increase right-of-use assets and lease liabilities in Edison International's and SCE's consolidated balance sheets. Edison International and SCE are currently evaluating the impact this standard will have on the results of operations and statements of cash flows.
In June 2016, the FASB issued an accounting standards update to amend the guidance on the impairment of financial instruments. The new guidance adds an impairment model, known as the current expected credit loss model, which is based on expected losses rather than incurred losses. This guidance applies to most debt instruments, trade receivables, lease receivables, financial guarantee contracts, and loan commitments. This guidance is effective on January 1, 2020. Edison International and SCE are currently evaluating this new guidance.
In August and November 2016, the FASB issued accounting standards updates to amend the guidance on the presentation and classification of certain cash receipts and cash payments in the statement of cash flows to reduce diversity in practice. This guidance addresses eight specific cash flow classification issues, including debt prepayment or extinguishment costs, proceeds from the settlement of corporate-owned life insurance, distributions received from equity method investments and restricted cash. This standard also clarifies the application of the predominance principle where cash receipts and payments have aspects of more than one class of cash flows. The new standard is effective on January 1, 2018. Edison International and SCE are currently evaluating this new guidance.
In January 2017, the FASB issued an accounting standards update to simplify the accounting for goodwill impairment. This accounting standards update changes the procedural steps in applying the goodwill impairment test. A goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Edison International will apply this guidance to the goodwill impairment test beginning in 2020.

58



Note 2.    Property, Plant and Equipment
SCE's property, plant and equipment included in the consolidated balance sheets is composed of the following:
 
December 31,
(in millions)
2016
 
2015
Distribution
$
22,332

 
$
20,871

Transmission
12,549

 
11,592

Generation
3,376

 
3,138

General plant and other
4,633

 
4,543

Accumulated depreciation
(9,000
)
 
(8,548
)
 
33,890

 
31,596

Construction work in progress
2,790

 
3,218

Nuclear fuel, at amortized cost
126

 
131

Total utility property, plant and equipment
$
36,806

 
$
34,945

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. Capitalized software costs, included in general plant and other above, were $1.4 billion at both December 31, 2016 and 2015 and accumulated amortization was $0.8 billion and $0.9 billion, at December 31, 2016 and 2015, respectively. Amortization expense for capitalized software was $249 million, $268 million and $271 million in 2016, 2015 and 2014, respectively. At December 31, 2016, amortization expense is estimated to be approximately $243 million annually for 2017 through 2021.
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.
The following is SCE's investment in each asset as of December 31, 2016:
(in millions)
Plant in Service
Construction Work in Progress
Accumulated
Depreciation
Nuclear Fuel
(at amortized cost)
Net Book Value
Ownership
Interest
Transmission systems:
 
 
 
 
 
 
Eldorado
$
235

$
10

$
21

$
—

$
224

59%
Pacific Intertie
192

21

80

—

133

50%
Generating station:
 
 
 
 
 
 
Palo Verde (nuclear)
1,959

62

1,547

126

600

16%
Total
$
2,386

$
93

$
1,648

$
126

$
957

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

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Note 3.    Variable Interest Entities
A VIE is defined as a legal entity that meets one of two conditions: (1) the equity owners do not have sufficient equity at risk, or (2) the holders of the equity investment at risk, as a group, lack any of the following three characteristics: decision-making rights, the obligation to absorb losses, or the right to receive the expected residual returns of the entity. The primary beneficiary is identified as the variable interest holder that has both the power to direct the activities of the VIE that most significantly impact the entity's economic performance and the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The primary beneficiary is required to consolidate the VIE. A subsidiary of Edison International is the primary beneficiary of entities that own 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 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 4,353 MW and 4,062 MW at December 31, 2016 and 2015, respectively, and the amounts that SCE paid to these projects were $788 million and $640 million for the years ended December 31, 2016 and 2015, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.
Unconsolidated Trusts of SCE
SCE Trust I, Trust II, Trust III, Trust IV and Trust V were formed in 2012, 2013, 2014, 2015 and 2016 respectively, for the exclusive purpose of issuing the 5.625%, 5.10%, 5.75%, 5.375% and 5.45% 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, Trust IV and Trust V issued to the public trust securities in the face amounts of $475 million, $400 million, $275 million, $325 million and $300 million (cumulative, liquidation amounts of $25 per share), respectively, and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series F, Series G, Series H, Series J and Series K Preference Stock issued by SCE in the principal amounts of $475 million, $400 million, $275 million, $325 million and $300 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities.
The Series F, Series G, Series H, Series J and Series K 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, Series J or Series K 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 if and when the SCE board of directors declares and makes dividend payments on the related Preference Stock. The applicable trust will use any dividends it receives on the related Preference Stock to make its corresponding distributions on the applicable series of trust securities. If SCE does not make a dividend payment to any of these trusts, SCE would be prohibited from paying dividends on its common stock. SCE has fully and unconditionally guaranteed the payment of the trust securities and trust distributions, if and when SCE pays dividends on the related Preference Stock.

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The Trust I, Trust II, Trust III and Trust IV balance sheets as of December 31, 2016 and 2015 consisted of investments of $475 million, $400 million, $275 million and $325 million in the Series F, Series G, Series H and Series J Preference Stock respectively, $475 million, $400 million, $275 million and $325 million of trust securities, respectively and $10,000 each of common stock. The Trust V balance sheet as of December 31, 2016 consisted of investments of $300 million in the Series K Preference Stock, $300 million of trust securities, and $10,000 of common stock.
The following table provides a summary of the trusts' income statements:

Years ended December 31,
(in millions)
Trust I
 
Trust II
 
Trust III
 
Trust IV
 
Trust V
2016
 
 
 
 
 
 
 
 
 
Dividend income
$
27

 
$
20

 
$
16

 
$
17

 
$
13

Dividend distributions
27

 
20

 
16

 
17

 
13

2015
 
 
 
 
 
 
 
 
 
Dividend income
$
27

 
$
20

 
$
16

 
$
6

 
*

Dividend distributions
27

 
20

 
16

 
6

 
*

2014
 
 
 
 
 
 
 
 
 
Dividend income
$
27

 
$
20

 
$
13

 
*

 
*

Dividend distributions
27

 
20

 
13

 
*

 
*

* 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, 2016 and 2015, nonperformance risk was not material for Edison International and SCE.
Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.
Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds and money market funds.
Level 2 – Edison International's and SCE's Level 2 assets and liabilities include fixed income securities, primarily consisting of U.S. government and agency bonds, municipal bonds and corporate bonds, and over-the-counter derivatives. The fair value of fixed income securities is determined using a market approach by obtaining quoted prices for similar assets and liabilities in active markets and inputs that are observable, either directly or indirectly, for substantially the full term of the instrument.
The fair value of SCE's over-the-counter derivative contracts is determined using an income approach. SCE uses standard pricing models to determine the net present value of estimated future cash flows. Inputs to the pricing models include forward published or posted clearing prices from 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 tolling arrangements and derivative contracts that trade infrequently such as congestion revenue rights ("CRRs"). Edison International Parent and Other does not have any Level 3 assets and liabilities.

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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:
 
December 31, 2016
(in millions)
Level 1
 
Level 2
 
Level 3
 
Netting
and
Collateral1
 
Total
Assets at fair value
 
 
 
 
 
 
 
 
 
Derivative contracts
$
—

 
$
6

 
$
68

 
$
—

 
$
74

Other
33

 
—

 
—

 
—

 
33

Nuclear decommissioning trusts:
 
 
 
 
 
 
 
 
 
Stocks2
1,547

 
—

 
—

 
—

 
1,547

Fixed Income3
865

 
1,751

 
—

 
—

 
2,616

Short-term investments, primarily cash equivalents
36

 
170

 
—

 
—

 
206

Subtotal of nuclear decommissioning trusts4
2,448

 
1,921

 
—

 
—

 
4,369

Total assets
2,481

 
1,927

 
68

 
—

 
4,476

Liabilities at fair value
 
 
 
 
 
 
 
 
 
Derivative contracts
—

 
—

 
1,157

 
—

 
1,157

Total liabilities
—

 
—

 
1,157

 
—

 
1,157

Net assets (liabilities)
$
2,481

 
$
1,927

 
$
(1,089
)
 
$
—

 
$
3,319

 
December 31, 2015
(in millions)
Level 1
 
Level 2
 
Level 3
 
Netting
and
Collateral1
 
Total
Assets at fair value
 
 
 
 
 
 
 
 
 
Derivative contracts
$
—

 
$
—

 
$
163

 
$
—

 
$
163

Other
28

 
—

 
—

 
—

 
28

Nuclear decommissioning trusts:
 

 
 

 
 

 
 

 
 

Stocks2
1,460

 
—

 
—

 
—

 
1,460

Fixed Income3
947

 
1,776

 
—

 
—

 
2,723

Short-term investments, primarily cash equivalents
91

 
81

 
—

 
—

 
172

Subtotal of nuclear decommissioning trusts4
2,498

 
1,857

 
—

 
—

 
4,355

Total assets
2,526

 
1,857

 
163

 
—

 
4,546

Liabilities at fair value
 
 
 
 
 
 
 
 
 
Derivative contracts
—

 
22

 
1,311

 
(15
)
 
1,318

Total liabilities
—

 
22

 
1,311

 
(15
)
 
1,318

Net assets (liabilities)
$
2,526

 
$
1,835

 
$
(1,148
)
 
$
15

 
$
3,228


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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% of SCE's equity investments were located in the United States at both December 31, 2016 and 2015.
3 
Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $79 million and $111 million at December 31, 2016 and 2015, respectively.
4 
Excludes net payables of $127 million and $24 million at December 31, 2016 and 2015, 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 $23 million and $29 million at December 31, 2016 and 2015, 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:
 
 
December 31,
(in millions)
 
2016
 
2015
Fair value of net liabilities at beginning of period
 
$
(1,148
)
 
$
(902
)
Total realized/unrealized gains (losses):
 
 
 
 
Included in regulatory assets and liabilities1
 
59

 
(246
)
Fair value of net liabilities at end of period
 
$
(1,089
)
 
$
(1,148
)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period
 
$
(70
)
 
$
(311
)
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 2016 and 2015.
Valuation Techniques Used to Determine Fair Value
The process of determining fair value is the responsibility of SCE's risk management department, which reports 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.

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The following table sets forth SCE's valuation techniques and significant unobservable inputs used to determine fair value for significant Level 3 assets and liabilities:
 
Fair Value (in millions)
 
Significant
Range
 
Assets
 
Liabilities
Valuation Technique(s)
Unobservable Input
(Weighted Average)
Congestion revenue rights
 
 
 
December 31, 2016
$
67

 
$
—

Market simulation model and auction prices
Load forecast
3,708 MW - 22,840 MW
 
 
 
 
 
Power prices1
$3.65 - $99.58
 
 
 
 
 
Gas prices2
$2.51 - $4.87
December 31, 2015
152

 
—

Market simulation model and auction prices
Load forecast
6,289 MW - 24,349 MW
 
 
 
 
 
Power prices1
$0 - $110.44
 
 
 
 
 
Gas prices2
$1.98 - $5.72
Tolling
 
 
 
 
 
 
December 31, 2016
—

 
1,154

Option model
Volatility of gas prices
15% - 48% (20%)
 
 
 
 
 
Volatility of power prices
29% - 71% (40%)
 
 
 
 
 
Power prices
$23.40 - $51.24 ($34.70)
December 31, 2015
10

 
1,297

Option model
Volatility of gas prices
15% - 58% (20%)
 
 
 
 
 
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.
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

64



corroborate as described below. The trustee monitors prices supplied by pricing services, including reviewing prices against defined parameters' tolerances and performs research and resolves variances beyond the set parameters. SCE corroborates the fair values of securities by comparison to other market-based price sources obtained by SCE's investment managers. Differences outside established thresholds are followed-up with the trustee and resolved. For each reporting period, SCE reviews the trustee determined fair value hierarchy and overrides the trustee level classification when appropriate.
Fair Value of Debt Recorded at Carrying Value
The carrying value and fair value of Edison International's and SCE's long-term debt (including current portion of long-term debt) are as follows:
 
December 31, 2016
 
December 31, 2015
(in millions)
Carrying
Value1
 
Fair
Value
 
Carrying
Value1
 
Fair
Value
Edison International
$
11,156

 
$
12,368

 
$
11,178

 
$
12,252

SCE
10,333

 
11,539

 
10,539

 
11,592

1  
Carrying value is net of debt issuance costs.
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.
Note 5.    Debt and Credit Agreements
Long-Term Debt
The following table summarizes long-term debt (rates and terms are as of December 31, 2016) of Edison International and SCE:
 
December 31,
(in millions)
2016
 
2015
Edison International Parent and Other:
 
 
 
Debentures and notes:
 
 
 
2017 – 2023 (2.95% to 3.75%)
$
800

 
$
614

Other long-term debt
32

 
31

Current portion of long-term debt
(402
)
 
(216
)
Unamortized debt discount and issuance costs, net
(9
)
 
(6
)
Total Edison International Parent and Other
421

 
423

SCE:
 
 
 
First and refunding mortgage bonds:
 
 
 
2017 – 2045 (1.125% to 6.05%)
9,357

 
9,436

Pollution-control bonds:
 
 
 
2028 – 2035 (1.375% to 5.0%)1
774

 
909

Debentures and notes:
 
 
 
2029 – 2053 (5.06% to 6.65%)
307

 
307

Current portion of long-term debt
(579
)
 
(79
)
Unamortized debt discount and issuance costs, net
(105
)
 
(113
)
Total SCE
9,754

 
10,460

Total Edison International
$
10,175

 
$
10,883

1 
Excludes 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 and 2033 at December 31, 2016 and 2031 at December 31, 2015.

65



Edison International and SCE long-term debt maturities over the next five years are the following:
(in millions)
Edison International
 
SCE
2017
$
981

 
$
579

2018
482

 
479

2019
82

 
79

2020
80

 
79

2021
580

 
579

Project Financings
As of December 31, 2016 and 2015, indirect subsidiaries of Edison Energy Group owning solar projects had approximately $22 million and $25 million outstanding under a 7-year term financing due in 2022 at a weighted average interest rate of 3.50% and 3.11%. In addition, 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 Energy Group 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 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.
An indirect subsidiary of Edison Energy Group also entered into a non-recourse debt financing to support equity contributions in certain solar projects through June 30, 2017. The maturity date of the borrowings under this agreement is December 31, 2036. As of December 31, 2016 and 2015, there was $10 million and $6 million outstanding under this agreement at a weighted average interest rate of 9%.
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, 2016, 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, 2016:
(in millions)
Edison International Parent
 
SCE
Commitment
$
1,250

 
$
2,750

Outstanding borrowings
(538
)
 
(769
)
Outstanding letters of credit
—

 
(91
)
Amount available
$
712

 
$
1,890

SCE and Edison International Parent have multi-year revolving credit facilities of $2.75 billion and $1.25 billion, respectively, with both maturing in July 2021. 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, 2016, commercial paper supported by SCE's credit facility, net of discount, was $769 million at a weighted-average interest rate of 0.9%. At December 31, 2016, letters of credit issued under SCE's credit facility aggregated $91 million and are scheduled to expire in twelve months or less. At December 31, 2015, the outstanding commercial paper, net of discount, was $49 million at a weighted-average interest rate of 0.51%.

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At December 31, 2016, Edison International Parent's outstanding commercial paper, net of discount, was $538 million at a weighted-average interest rate of 0.97%. This commercial paper was supported by the $1.25 billion multi-year revolving credit facility. At December 31, 2015, the outstanding commercial paper, net of discount, was $646 million at a weighted-average interest rate of 0.78%.
Debt Financing Subsequent to December 31, 2016
In January 2017, SCE borrowed $300 million under a Term Loan Agreement with a variable interest rate, initially set at 1.483%, due in July 2018. The proceeds were used for general corporate purposes.
In January 2017, SCE reissued $135 million of 2.625% pollution-control bonds with a mandatory purchase date in December 2023. These bonds mature in November 2033. The proceeds were used for general corporate purposes.
Note 6.    Derivative Instruments
Derivative financial instruments are used to manage exposure to commodity price risk. These risks are managed in part by entering into forward commodity transactions, including options, swaps and futures. To mitigate credit risk from counterparties in the event of nonperformance, master netting agreements are used whenever possible and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.
Commodity Price Risk
Commodity price risk represents the potential impact that can be caused by a change in the market value of a particular commodity. SCE's electricity price exposure arises from energy purchased from and sold to wholesale markets as a result of differences between SCE's load requirements and the amount of energy delivered from its generating facilities and 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 $12 million and $38 million as of December 31, 2016 and 2015, respectively, for which SCE has posted $12 million collateral and no collateral to its counterparties at the respective dates for its derivative liabilities and related outstanding payables. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2016, SCE would be required to post $4 million of additional collateral of which $4 million is related to outstanding payables that are net of collateral already posted.

67



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:
 
 
December 31, 2016
 
 
 
 
Derivative Assets
 
Derivative Liabilities
 
Net Liability
(in millions)
 
Short-Term
 
Long-Term
 
Subtotal
 
Short-Term
 
Long-Term
 
Subtotal
 
Commodity derivative contracts
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
74

 
$
1

 
$
75

 
$
217

 
$
941

 
$
1,158

 
$
1,083

Gross amounts offset in consolidated balance sheets
 
(1
)
 
—

 
(1
)
 
(1
)
 
—

 
(1
)
 
—

Cash collateral posted1
 
—

 
—

 
—

 
—

 
—

 
—

 
—

Net amounts presented in the consolidated balance sheets
 
$
73

 
$
1

 
$
74

 
$
216

 
$
941

 
$
1,157

 
$
1,083


 
 
December 31, 2015
 
 
 
 
Derivative Assets
 
Derivative Liabilities
 
Net Liability
(in millions)
 
Short-Term
 
Long-Term
 
Subtotal
 
Short-Term
 
Long-Term
 
Subtotal
 
Commodity derivative contracts
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
81

 
$
84

 
$
165

 
$
235

 
$
1,100

 
$
1,335

 
$
1,170

Gross amounts offset in consolidated balance sheets
 
(2
)
 
—

 
(2
)
 
(2
)
 
—

 
(2
)
 
—

Cash collateral posted1
 
—

 
—

 
—

 
(15
)
 
—

 
(15
)
 
(15
)
Net amounts presented in the consolidated balance sheets
 
$
79

 
$
84

 
$
163

 
$
218

 
$
1,100

 
$
1,318

 
$
1,155

1 
In addition, at December 31, 2016, SCE received $2 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015, SCE had posted $31 million of cash 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:
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Realized losses
 
$
(59
)
 
$
(148
)
 
$
(57
)
Unrealized gains (losses)
 
84

 
(182
)
 
(147
)

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Notional Volumes of Derivative Instruments
The following table summarizes the notional volumes of derivatives used for SCE hedging activities:
 
 
Economic Hedges
 
Unit of
December 31,
Commodity
Measure
2016
 
2015
Electricity options, swaps and forwards
GWh
1,816

 
6,221
Natural gas options, swaps and forwards
Bcf
36

 
32
Congestion revenue rights
GWh
93,319

 
109,740
Tolling arrangements
GWh
61,093

 
70,663
Note 7.    Income Taxes
Current and Deferred Taxes
Edison International's sources of income (loss) before income taxes are:
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
Income from continuing operations before income taxes
 
$
1,590

 
$
1,568

 
$
1,979

Income (loss) from discontinued operations before income taxes
 
1

 
15

 
(525
)
Income before income tax
 
$
1,591

 
$
1,583

 
$
1,454

The components of income tax expense (benefit) by location of taxing jurisdiction are:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Current:
 
 
 
 
 
 
 
 
 
 
 
Federal
$
(46
)
 
$
18

 
$
(99
)
 
$
75

 
$
72

 
$
(89
)
State
33

 
19

 
20

 
93

 
127

 
101

 
(13
)
 
37

 
(79
)
 
168

 
199

 
12

Deferred:
 
 
 
 
 
 
 
 
 
 
 
Federal
176

 
340

 
454

 
112

 
298

 
476

State
14

 
109

 
68

 
(24
)
 
10

 
(14
)
 
190

 
449

 
522

 
88

 
308

 
462

Total continuing operations
177

 
486

 
443

 
256

 
507

 
474

Discontinued operations1
(11
)
 
(21
)
 
(710
)
 
—

 
—

 
—

Total
$
166

 
$
465

 
$
(267
)
 
$
256

 
$
507

 
$
474

1 
See Note 15 for a discussion of discontinued operations related to EME.

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The components of net accumulated deferred income tax liability are:
 
Edison International
 
SCE
 
December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Deferred tax assets:
 
 
 
 
 
 
 
Property and software related
$
549

 
$
675

 
$
548

 
$
675

Nuclear decommissioning trust assets in excess of nuclear ARO liability
348

 
360

 
348

 
360

Loss and credit carryforwards
1,418

 
1,388

 
—

 
—

Regulatory balancing accounts
15

 
21

 
15

 
21

Pension and PBOPs
300

 
337

 
93

 
154

Other
419

 
499

 
408

 
411

Sub-total
3,049

 
3,280

 
1,412

 
1,621

Less valuation allowance
24

 
32

 
—

 
—

Total
3,025

 
3,248

 
1,412

 
1,621

Deferred tax liabilities:
 
 
 
 
 
 
 
Property-related
10,330

 
9,606

 
10,330

 
9,600

Capitalized software costs
237

 
207

 
237

 
207

Regulatory balancing accounts
134

 
202

 
134

 
202

Nuclear decommissioning trust assets
348

 
360

 
348

 
360

PBOPs
13

 
71

 
13

 
71

Other
202

 
189

 
148

 
161

Total
11,264

 
10,635

 
11,210

 
10,601

Accumulated deferred income tax liability, net1
$
8,239

 
$
7,387

 
$
9,798

 
$
8,980

1  
Included in deferred income taxes and credits.
Net Operating Loss and Tax Credit Carryforwards
The amounts of net operating loss and tax credit carryforwards (after-tax) are as follows:
 
Edison International
 
SCE
 
December 31, 2016
(in millions)
Loss Carryforwards
 
Credit Carryforwards
 
Loss Carryforwards
 
Credit Carryforwards
Expire between 2017 to 2035
$
1,095

 
$
430

 
$
20

 
$
25

No expiration date
—

 
69

 
—

 
37

Total1
$
1,095

 
$
499

 
$
20

 
$
62

1
Deferred tax assets for net operating loss and tax credit carryforwards are reduced by unrecognized tax benefits of $176 million and $82 million for Edison International and SCE, respectively.
Edison International has recorded a valuation allowance of $24 million for state net operating loss carryforwards estimated to expire unused. In 2016, Edison International determined that $8 million of the assets subject to a valuation allowance, had no expectation of recovery and were written off.
At December 31, 2015, Edison International and SCE had $42 million and $6 million, respectively, of 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. In March 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. As part of this new guidance adopted in 2016, Edison International and SCE recorded an increase to beginning retained earnings for these amounts. Refer to Note 1 for further information.
Edison International consolidates for federal income tax purposes, but not for financial accounting purposes, a group of wind projects referred to as Capistrano Wind. The amount of net operating loss and tax credit carryforwards recognized as part of deferred income taxes includes $242 million and $210 million related to Capistrano Wind at December 31, 2016 and 2015,

70



respectively. 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:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Income from continuing operations before income taxes
$
1,590

 
$
1,568

 
$
1,979

 
$
1,755

 
$
1,618

 
$
2,039

Provision for income tax at federal statutory rate of 35%
556

 
549

 
693

 
614

 
566

 
714

Increase in income tax from:
 

 
 

 
 

 
 

 
 

 
 
Items presented with related state income tax, net:
 

 
 

 
 

 
 

 
 

 
 
    Regulatory asset write-off1
—

 
382

 
—

 
—

 
382

 
—

State tax, net of federal benefit
29

 
5

 
56

 
43

 
34

 
55

Property-related2
(362
)
 
(341
)
 
(252
)
 
(362
)
 
(341
)
 
(252
)
Change related to uncertain tax positions
(4
)
 
(67
)
 
5

 
(8
)
 
(94
)
 
12

San Onofre OII settlement
—

 
—

 
(23
)
 
—

 
—

 
(23
)
Share-based compensation3
(28
)
 
—

 
—

 
(13
)
 
—

 
—

Other
(14
)
 
(42
)
 
(36
)
 
(18
)
 
(40
)
 
(32
)
Total income tax expense from continuing operations
$
177

 
$
486

 
$
443

 
$
256

 
$
507

 
$
474

Effective tax rate
11.1
%
 
31.0
%
 
22.4
%
 
14.6
%
 
31.3
%
 
23.2
%
1 Includes federal and state.
2 
Includes incremental repair benefits. See discussion of repair deductions below.
3 
Includes state taxes of $(4) million and $(1) million for Edison International and SCE, respectively. Refer to Note 1 for further information.
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 GRC proceedings. Incremental repair deductions for the years 2012 – 2014 resulted in additional income tax benefits of $133 million in 2014.
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 in 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. 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 April 2016,

71



the CPUC granted SCE's request to reduce SCE's BRRBA by $234 million in future periods subject to the timing and final outcome of audits that may be conducted by tax authorities. The refunds will result in flowing incremental tax benefits for 2012 – 2014 to customers. SCE refunded $133 million ($79 million after-tax) during the second quarter of 2016. SCE did not record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings.
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:
 
Edison International
 
SCE
 
December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Balance at January 1,
$
529

 
$
576

 
$
815

 
$
353

 
$
441

 
$
532

Tax positions taken during the current year:
 
 
 
 
 
 
 
 
 
 
 
Increases
36

 
54

 
65

 
36

 
48

 
57

Tax positions taken during a prior year:
 
 
 
 
 
 
 
 
 
 
 
Increases
2

 
66

 
1

 
—

 
23

 
—

Decreases1
(96
)
 
(165
)
 
(143
)
 
(18
)
 
(159
)
 
(93
)
Decreases for settlements during the period2
—

 
(2
)
 
(162
)
 
—

 
—

 
(55
)
Balance at December 31,
$
471

 
$
529

 
$
576

 
$
371

 
$
353

 
$
441

1
Decreases in prior year tax positions for 2016 relate to state tax receivables on various claims. Due to the tax risks associated with these claims, the tax benefits were fully reserved at the time the asset was recorded. During 2016, the Company has determined that it will not recognize these assets so the tax benefit and related tax reserve were written off. Decreases in tax positions for 2015 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
In the fourth quarter of 2014, Edison International has settled all open tax positions with the IRS for taxable years 2003 through 2006.
As of December 31, 2016 and 2015, if recognized, $347 million and $440 million, respectively, of the unrecognized tax benefits would impact Edison International's effective tax rate; and $243 million and $256 million, respectively, of the unrecognized tax benefits would impact SCE's effective tax rate.
Tax Disputes
Tax Years 2007 – 2012
Edison International has reached a tentative settlement agreement with the IRS for the 2007 – 2012 tax years. The final agreement, when approved, is not expected to have a material impact on the financial statements.
During 2015, the Company received the IRS Revenue Agent Report for the 2010 – 2012 tax years. Edison International's and SCE's tax reserves were re-measured at that time and $94 million and $100 million, respectively, of income tax benefits were recorded in the comparable quarter for the prior year.
Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2007 – 2015 and 2003 – 2015, respectively.

72



Accrued Interest and Penalties
The total amount of accrued interest and penalties related to income tax liabilities for continuing and discontinued operations are:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Accrued interest and penalties
$
128

 
$
122

 
$
41

 
$
40

The net after-tax interest and penalties recognized in income tax expense for continuing and discontinued operations are:
 
Edison International
 
SCE
 
December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Net after-tax interest and penalties tax benefit
$
6

 
$
9

 
$
41

 
$
2

 
$
14

 
$
16

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:
 
Edison International
 
SCE
(in millions)
Years ended December 31,
2016
$
69

 
$
68

2015
73

 
72

2014
71

 
70

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 $136 million and $85 million, respectively, for the year ending December 31, 2017. Annual contributions made by SCE to most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms.
The funded position of Edison International's pension is sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's pension are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, a regulatory asset has been recorded equal to the unfunded status (See Note 10).

73



Information on pension plan assets and benefit obligations for continuing and discontinued operations is shown below.
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Change in projected benefit obligation
 
 
 
 
 
 
 
Projected benefit obligation at beginning of year
$
4,374

 
$
4,517

 
$
3,878

 
$
3,999

Service cost
139

 
142

 
132

 
133

Interest cost
171

 
170

 
150

 
150

Actuarial gain
(125
)
 
(149
)
 
(140
)
 
(143
)
Benefits paid
(275
)
 
(305
)
 
(229
)
 
(261
)
Other
—

 
(1
)
 
—

 
—

Projected benefit obligation at end of year
$
4,284

 
$
4,374

 
$
3,791

 
$
3,878

Change in plan assets
 
 
 
 
 
 
 
Fair value of plan assets at beginning of year
$
3,298

 
$
3,454

 
$
3,080

 
$
3,217

Actual return on plan assets
262

 
30

 
239

 
27

Employer contributions
103

 
119

 
82

 
97

Benefits paid
(275
)
 
(305
)
 
(229
)
 
(261
)
Fair value of plan assets at end of year
$
3,388

 
$
3,298

 
$
3,172

 
$
3,080

Funded status at end of year
$
(896
)
 
$
(1,076
)
 
$
(619
)
 
$
(798
)
Amounts recognized in the consolidated balance sheets consist of 1:
 
 
 
 
 
 
 
Long-term assets
$
2

 
$
—

 
$
—

 
$
—

Current liabilities
(50
)
 
(27
)
 
(4
)
 
(4
)
Long-term liabilities
(848
)
 
(1,049
)
 
(615
)
 
(794
)
 
$
(896
)
 
$
(1,076
)
 
$
(619
)
 
$
(798
)
Amounts recognized in accumulated other comprehensive loss consist of:
 
 
 
 
 
 
 
Prior service cost
$
(1
)
 
$
—

 
$
—

 
$
—

Net loss1
93

 
96

 
24

 
27

 
$
92

 
$
96

 
$
24

 
$
27

Amounts recognized as a regulatory asset
$
574

 
$
675

 
$
574

 
$
675

Total not yet recognized as expense
$
666

 
$
771

 
$
598

 
$
702

Accumulated benefit obligation at end of year
$
4,138

 
$
4,200

 
$
3,683

 
$
3,744

Pension plans with an accumulated benefit obligation in excess of plan assets:
 
 
 
 
 
 
 
Projected benefit obligation
$
4,284

 
$
4,374

 
$
3,791

 
$
3,878

Accumulated benefit obligation
4,138

 
4,200

 
3,683

 
3,744

Fair value of plan assets
3,388

 
3,298

 
3,172

 
3,080

Weighted-average assumptions used to determine obligations at end of year:
 
 
 
 
 
 
 
Discount rate
3.94
%
 
4.18
%
 
3.94
%
 
4.18
%
Rate of compensation increase
4.00
%
 
4.00
%
 
4.00
%
 
4.00
%
1 
The SCE liability excludes a long-term payable due to Edison International Parent of $124 million and $123 million at December 31, 2016 and 2015, respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent. SCE's accumulated other comprehensive loss of $24 million and $27 million at December 31, 2016 and 2015, respectively, excludes net loss of $20 million and $18 million related to these benefits.

74



Pension expense components for continuing operations are:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Service cost
$
139

 
$
142

 
$
133

 
$
136

 
$
139

 
$
128

Interest cost
172

 
170

 
181

 
156

 
155

 
164

Expected return on plan assets
(220
)
 
(233
)
 
(229
)
 
(205
)
 
(217
)
 
(213
)
Settlement costs1
—

 
—

 
45

 
—

 
—

 
42

Curtailment gain
—

 
—

 
(4
)
 
—

 
—

 
—

Amortization of prior service cost
4

 
5

 
5

 
4

 
5

 
5

Amortization of net loss2
27

 
40

 
12

 
23

 
35

 
7

Expense under accounting standards
122

 
124

 
143

 
114

 
117

 
133

Regulatory adjustment (deferred)
(21
)
 
(6
)
 
8

 
(21
)
 
(6
)
 
8

Total expense recognized
$
101

 
$
118

 
$
151

 
$
93

 
$
111

 
$
141

1 
Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International was zero for the both the years ended December 31, 2016 and 2015 and $3 million for the year ended December 31, 2014.
2 
Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $10 million and $6 million, respectively, for the year ended December 31, 2016. 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 from the SCE Retirement Plan (primarily due to workforce reductions described below) exceeded the estimated service and interest costs for that year. 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.
Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing operations:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Net loss (gain)
$
6

 
$
7

 
$
85

 
$
4

 
$
(9
)
 
$
37

Amortization of net loss and other
(10
)
 
(15
)
 
(13
)
 
(6
)
 
(9
)
 
(4
)
Total recognized in other comprehensive loss
$
(4
)
 
$
(8
)
 
$
72

 
$
(2
)
 
$
(18
)
 
$
33

Total recognized in expense and other comprehensive loss
$
97

 
$
110

 
$
223

 
$
91

 
$
93

 
$
174


75



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 2017 for continuing operations are as follows:
(in millions)
Edison International
 
SCE
Unrecognized net loss to be amortized1
$
19

 
$
15

Unrecognized prior service cost to be amortized
3

 
3

1 
The amount of net loss expected to be reclassified from other comprehensive loss for Edison International's continuing operations and SCE is $10 million and $6 million, respectively.
Edison International and SCE used the following weighted-average assumptions to determine pension expense for continuing operations:
 
Years ended December 31,
 
2016
 
2015
 
2014
Discount rate
4.18
%
 
3.85
%
 
4.50
%
Rate of compensation increase
4.00
%
 
4.00
%
 
4.00
%
Expected long-term return on plan assets
7.00
%
 
7.00
%
 
7.00
%
The following benefit payments, which reflect expected future service, are expected to be paid:
 
Edison International
 
SCE
(in millions)
Years ended December 31,
2017
$
346

 
$
271

2018
332

 
298

2019
344

 
300

2020
341

 
304

2021
341

 
304

2022 – 2026
1,566

 
1,396

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, age, hire date, and retirement date. Under the terms of the Edison International Welfare Benefit Plan ("PBOP Plan") each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of all PBOP 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 $21 million for the year ended December 31, 2017. 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

76



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:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Change in benefit obligation
 
 
 
 
 
 
 
Benefit obligation at beginning of year
$
2,350

 
$
2,784

 
$
2,341

 
$
2,775

Service cost
35

 
46

 
34

 
46

Interest cost
97

 
102

 
97

 
102

Special termination benefits
2

 
(2
)
 
2

 
(2
)
Plan Amendments
(6
)
 
—

 
(6
)
 
—

Actuarial gain
(110
)
 
(500
)
 
(110
)
 
(500
)
Plan participants' contributions
19

 
20

 
19

 
20

Benefits paid
(111
)
 
(100
)
 
(111
)
 
(100
)
Benefit obligation at end of year
$
2,276

 
$
2,350

 
$
2,266

 
$
2,341

Change in plan assets
 
 
 
 
 
 
 
Fair value of plan assets at beginning of year
$
2,036

 
$
2,086

 
$
2,036

 
$
2,086

Actual return on assets
137

 
6

 
137

 
6

Employer contributions
21

 
24

 
21

 
24

Plan participants' contributions
19

 
20

 
19

 
20

Benefits paid
(111
)
 
(100
)
 
(111
)
 
(100
)
Fair value of plan assets at end of year
$
2,102

 
$
2,036

 
$
2,102

 
$
2,036

Funded status at end of year
$
(174
)
 
$
(314
)
 
$
(164
)
 
$
(305
)
Amounts recognized in the consolidated balance sheets consist of:
 
 
 
 
 
 
 
Current liabilities
$
(14
)
 
$
(15
)
 
$
(13
)
 
$
(15
)
Long-term liabilities
(160
)
 
(299
)
 
(151
)
 
(290
)
 
$
(174
)
 
$
(314
)
 
$
(164
)
 
$
(305
)
Amounts recognized in accumulated other comprehensive loss consist of:
 
 
 
 
 
 
 
    Net loss
$
4

 
$
4

 
$
—

 
$
—

Amounts recognized as a regulatory asset
$
136

 
$
174

 
$
136

 
$
174

Total not yet recognized as expense
$
140

 
$
178

 
$
136

 
$
174

Weighted-average assumptions used to determine obligations at end of year:
 
 
 
 
 
 
 
Discount rate
4.29
%
 
4.55
%
 
4.29
%
 
4.55
%
Assumed health care cost trend rates:
 
 
 
 
 
 
 
Rate assumed for following year
7.00
%
 
7.50
%
 
7.00
%
 
7.50
%
Ultimate rate
5.00
%
 
5.00
%
 
5.00
%
 
5.00
%
Year ultimate rate reached
2022

 
2022

 
2022

 
2022

During 2016 and 2015, the PBOP plan had actuarial gains of $110 million and $500 million, respectively. The 2016 actuarial gain is primarily related to $165 million in experience gain, offsetting by $95 million loss from a decrease in the discount rate (from 4.55% as of December 31, 2015 to 4.29% as of December 31, 2016), and the adoption of new mortality tables, as discussed below. The 2015 actuarial gain is 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.

77



In 2016 and 2015, 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, 2016 and 2015, this adoption resulted in a change in Edison International's PBOP plans' accumulated postretirement benefit obligation of $(40) million and $(62) million, respectively, including $(40) million and $(61) million, respectively, for SCE.
PBOP expense components for continuing operations are:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Service cost
$
35

 
$
46

 
$
40

 
$
34

 
$
46

 
$
40

Interest cost
97

 
102

 
117

 
97

 
102

 
117

Expected return on plan assets
(112
)
 
(116
)
 
(108
)
 
(112
)
 
(116
)
 
(108
)
Special termination benefits1
2

 
1

 
3

 
2

 
1

 
3

Amortization of prior service credit
(2
)
 
(12
)
 
(36
)
 
(2
)
 
(12
)
 
(35
)
Amortization of net loss
—

 
3

 
6

 
—

 
2

 
5

Total expense
$
20

 
$
24

 
$
22

 
$
19

 
$
23

 
$
22

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 2017 for continuing operations are as follows:
    
Edison International
 
SCE
Unrecognized prior service credit to be amortized
$
(2
)
 
$
(2
)
Edison International and SCE used the following weighted-average assumptions to determine PBOP expense for continuing operations:
 
Years ended December 31,
 
2016
 
2015
 
2014
Discount rate
4.55
%
 
4.16
%
 
5.00
%
Expected long-term return on plan assets
5.60
%
 
5.50
%
 
5.50
%
Assumed health care cost trend rates:
 
 
 
 
 
Current year
7.50
%
 
7.75
%
 
7.75
%
Ultimate rate
5.00
%
 
5.00
%
 
5.00
%
Year ultimate rate reached
2022

 
2021

 
2020

A one-percentage-point change in assumed health care cost trend rate would have the following effects on continuing operations:
 
Edison International
 
SCE
(in millions)
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, 2016
$
244

 
$
(200
)
 
$
243

 
$
(199
)
Effect on annual aggregate service and interest costs
11

 
(9
)
 
11

 
(9
)

78



The following benefit payments are expected to be paid:
 
Edison International
 
SCE
(in millions)
Years ended December 31,
2017
$
98

 
$
98

2018
102

 
102

2019
105

 
105

2020
109

 
109

2021
113

 
112

2022 – 2026
612

 
609

Plan Assets
Description of Pension and Postretirement Benefits Other than Pensions Investment Strategies
The investment of plan assets is overseen by a fiduciary investment committee. Plan assets are invested using a combination of asset classes, and may have active and passive investment strategies within asset classes. Target allocations for 2016 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 2016 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.

79



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. The fair value of the underlying investments in equity mutual funds are based on stock-exchange prices. The fair value of the underlying investments in fixed-income mutual funds and other fixed income securities including municipal bonds are based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information. Foreign exchange and interest rate contracts are classified as Level 2 because the values are based on observable prices but are not traded on an exchange. Futures contracts trade on an exchange and therefore are classified as Level 1. Common/collective funds and partnerships are measured at fair value using the net asset value per share ("NAV") and have not been classified in the fair value hierarchy. Other investment entities are valued similarly to common/collective funds and are therefore classified as NAV. The Level 1 registered investment companies are either mutual or money market funds. The remaining funds in this category are readily redeemable and classified as NAV and are discussed further at Note 8 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.

80



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, 2016 by asset class and level within the fair value hierarchy:
(in millions)
Level 1
 
Level 2
 
Level 3
 
NAV1
 
Total
U.S. government and agency securities2
$
217

 
$
309

 
$
—

 
$
—

 
$
526

Corporate stocks3
720

 
15

 
—

 
—

 
735

Corporate bonds4
—

 
725

 
—

 
—

 
725

Common/collective funds5
—

 
—

 
—

 
692

 
692

Partnerships/joint ventures6
—

 
—

 
—

 
333

 
333

Other investment entities7
—

 
—

 
—

 
253

 
253

Registered investment companies8
124

 
—

 
—

 
6

 
130

Interest-bearing cash
42

 
—

 
—

 
—

 
42

Other
—

 
112

 
—

 
—

 
112

Total
$
1,103

 
$
1,161

 
$
—

 
$
1,284

 
$
3,548

Receivables and payables, net
 

 
 

 
 
 
 

 
(160
)
Net plan assets available for benefits
 

 
 

 
 
 
 

 
$
3,388

SCE's share of net plan assets
 
 
 
 
 
 
 
 
$
3,172

The following table sets forth the Master Trust investments 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
 
NAV1
 
Total
U.S. government and agency securities2
$
127

 
$
298

 
$
—

 
$
—

 
$
425

Corporate stocks3
720

 
16

 
—

 
—

 
736

Corporate bonds4
—

 
755

 
—

 
—

 
755

Common/collective funds5
—

 
—

 
—

 
640

 
640

Partnerships/joint ventures6
—

 
—

 
—

 
325

 
325

Other investment entities7
—

 
—

 
—

 
263

 
263

Registered investment companies8
117

 
—

 
—

 
4

 
121

Interest-bearing cash
6

 
—

 
—

 
—

 
6

Other
1

 
96

 
—

 
—

 
97

Total
$
971

 
$
1,165

 
$
—

 
$
1,232

 
$
3,368

Receivables and payables, net
 

 
 

 
 
 
 

 
(70
)
Net plan assets available for benefits
 

 
 

 
 
 
 

 
$
3,298

SCE's share of net plan assets
 
 
 
 
 
 
 
 
$
3,080

1 
These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
2 
Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal National Mortgage Association and the Federal Home Loan Mortgage Corporation.
3 
Corporate stocks are diversified. At December 31, 2016 and 2015, respectively, performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (62%) and (59%) and Morgan Stanley Capital International (MSCI) index (38%) and (41%).
4 
Corporate bonds are diversified. At December 31, 2016 and 2015, respectively, this category includes $76 million and $123 million for collateralized mortgage obligations and other asset backed securities of which $27 million and $25 million are below investment grade.

81



5 
At December 31, 2016 and 2015, 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 (45% and 46%) and Russell 1000 indexes (15% and 14%). At December 31, 2016 and 2015, 15% and 16% of the assets in this category are in index funds which seek to track performance in the MSCI All Country World Index exUS and MSCI Europe, Australasia and Far East (EAFE) Index, respectively. A non-index U.S. equity fund representing 23% and 22% of this category for 2016 and 2015, respectively, is actively managed.
6 
At December 31, 2016 and 2015, respectively, 55% and 51% are invested in private equity funds with investment strategies that include branded consumer products, clean technology and California geographic focus companies, 22% and 20% are invested in publicly traded fixed income securities, 18% and 14% are invested in a broad range of financial assets in all global markets and 4% and 15% of the remaining partnerships are invested in asset backed securities, including distressed mortgages and commercial and residential loans and debt and equity of banks.
7 
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.
8 
Level 1 of registered investment companies primarily consisted of a global equity mutual fund which seeks to outperform the MSCI World Total Return Index. The funds classified as NAV primarily consisted of a fixed income securities fund.
At December 31, 2016 and 2015, respectively, approximately 69% and 63% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
Postretirement Benefits Other than Pensions
The following table sets forth the VEBA Trust assets for Edison International and SCE that were accounted for at fair value as of December 31, 2016 by asset class and level within the fair value hierarchy:
(in millions)
Level 1
 
Level 2
 
Level 3
 
NAV1
 
Total
U.S. government and agency securities2
$
222

 
$
59

 
$
—

 
$
—

 
$
281

Corporate stocks3
230

 
—

 
—

 
—

 
230

Corporate notes and bonds4
—

 
877

 
—

 
—

 
877

Common/collective funds5
—

 
—

 
—

 
462

 
462

Partnerships6
—

 
—

 
—

 
79

 
79

Registered investment companies7
48

 
—

 
—

 
1

 
49

Interest bearing cash
48

 
—

 
—

 
—

 
48

Other8
4

 
103

 
—

 
—

 
107

Total
$
552

 
$
1,039

 
$
—

 
$
542

 
$
2,133

Receivables and payables, net
 

 
 

 
 
 
 

 
(31
)
Combined net plan assets available for benefits
 

 
 

 
 
 
 

 
$
2,102


82



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:
(in millions)
Level 1
 
Level 2
 
Level 3
 
NAV1
 
Total
U.S. government and agency securities2
$
200

 
$
42

 
$
—

 
$
—

 
$
242

Corporate stocks3
222

 
—

 
—

 
—

 
222

Corporate notes and bonds4
—

 
867

 
—

 
—

 
867

Common/collective funds5
—

 
—

 
—

 
424

 
424

Partnerships6
—

 
—

 
—

 
93

 
93

Registered investment companies7
60

 
—

 
—

 
3

 
63

Interest bearing cash
31

 
—

 
—

 
—

 
31

Other8
5

 
113

 
—

 
—

 
118

Total
$
518

 
$
1,022

 
$
—

 
$
520

 
$
2,060

Receivables and payables, net
 

 
 

 
 
 
 

 
(24
)
Combined net plan assets available for benefits
 

 
 

 
 
 
 

 
$
2,036

1 
These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
2 
Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal Home Loan Mortgage Corporation and the Federal National Mortgage Association.
3 
Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (47%) and the MSCI All Country World Index (53%) for both 2016 and 2015.
4 
Corporate notes and bonds are diversified and include approximately $47 million and $27 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2016 and 2015, respectively.
5 
At December 31, 2016 and 2015, respectively, 39% and 38% of the common/collective assets are invested in a large cap index fund which seeks to track performance of the Russell 1000 index. 39% and 41% of the remaining 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. 18% and 17% in a non-index U.S. equity fund which is actively managed.
6 
At December 31, 2016 and 2015, respectively, 59% and 56% of the partnerships are invested in private equity and venture capital funds. Investment strategies for these funds include branded consumer products, clean and information technology and healthcare. 31% and 21% are invested in a broad range of financial assets in all global markets. 9% and 23% of the remaining partnerships category is invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks.
7 
Level 1 registered investment companies consist of a money market fund.
8 
Other includes $76 million and $97 million of municipal securities at December 31, 2016 and 2015, respectively.
At December 31, 2016 and 2015, respectively, approximately 63% and 71% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
Stock-Based Compensation
Edison International maintains a shareholder approved incentive plan (the 2007 Performance Incentive Plan) that includes stock-based compensation. The maximum number of shares of Edison International's common stock authorized to be issued or transferred pursuant to awards under the 2007 Performance Incentive Plan, as amended, is 66 million shares, plus the number of any shares awarded under Edison International's prior plans that are 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, 2016, Edison International had approximately 32 million shares remaining available for new award grants under its stock-based compensation plans.

83



The following table summarizes total expense and tax benefits (expense) associated with stock based compensation:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Stock-based compensation expense1:
 
 
 
 
 
 
 
 
 
 
 
   Stock options
$
14

 
$
14

 
$
16

 
$
7

 
$
8

 
$
8

   Performance shares
13

 
7

 
16

 
6

 
4

 
8

   Restricted stock units
6

 
7

 
7

 
3

 
4

 
4

   Other
1

 
1

 
1

 
—

 
—

 
—

Total stock-based compensation expense
$
34

 
$
29

 
$
40

 
$
16

 
$
16

 
$
20

Income tax benefits related to stock compensation expense
$
41

 
$
12

 
$
16

 
$
20

 
$
7

 
$
8

Excess tax benefits2
—

 
15

 
15

 
—

 
23

 
20

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, "Common stock" in Edison International's consolidated balance sheets and "Additional paid-in capital" in SCE's consolidated balance sheets. Edison International and SCE adopted the new accounting guidance for shared-based payments, see Note 1 for further information.
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:
 
Years ended December 31,
 
2016
 
2015
 
2014
Expected terms (in years)
5.9
 
5.9
 
6.0
Risk-free interest rate
1.2% – 2.2%
 
1.6% – 2.1%
 
1.8% – 2.1%
Expected dividend yield
2.5% – 3.0%
 
2.6% – 3.2%
 
2.4% – 2.7%
Weighted-average expected dividend yield
2.9%
 
2.6%
 
2.7%
Expected volatility
17.2% – 17.5%
 
16.4% – 17.0%
 
17.8% – 19.1%
Weighted-average volatility
17.4%
 
16.5%
 
18.9%
The expected term represents the period of time for which the options are expected to be outstanding and is primarily based on historical exercise and post-vesting cancellation experience and stock price history. The risk-free interest rate for periods within the contractual life of the option is based on a zero coupon U.S. Treasury STRIPS (separate trading of registered interest and principal of securities) whose maturity 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 2016. The volatility period used was 71 months, 71 months and 72 months at December 31, 2016, 2015 and 2014, respectively.

84



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, 2015
12,866,597

 
$
45.93

 
 
 
 

Granted
2,120,009

 
67.41

 
 
 
 

Expired
—

 
—

 
 
 
 

Forfeited
(274,166
)
 
64.02

 
 
 
 

Exercised
(3,167,939
)
 
42.93

 
 
 
 

Outstanding at December 31, 2016
11,544,501

 
50.26

 
6.02
 
 

Vested and expected to vest at December 31, 2016
11,437,110

 
50.12

 
5.99
 
$
250

Exercisable at December 31, 2016
7,685,341

 
$
43.99

 
4.93
 
$
215

SCE:
 
 
 
 
 
 
 
Outstanding at December 31, 2015
5,840,057

 
$
47.77

 
 
 
 

Granted
959,478

 
67.36

 
 
 
 

Expired
—

 
—

 
 
 
 

Forfeited
(120,842
)
 
61.96

 
 
 
 

Exercised
(1,705,053
)
 
44.59

 
 
 
 

Transfers, net
(246,224
)
 
59.29

 
 
 
 
Outstanding at December 31, 2016
4,727,416

 
51.81

 
6.24
 
 

Vested and expected to vest at December 31, 2016
4,667,784

 
51.63

 
6.21
 
$
95

Exercisable at December 31, 2016
2,782,770

 
$
44.04

 
4.84
 
$
78

At December 31, 2016, 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)
Edison International
 
SCE
Unrecognized compensation cost, net of expected forfeitures
$
13

 
$
8

Weighted-average period (in years)
2.3

 
2.3


85



Supplemental Data on Stock Options
 
Edison International
 
SCE
 
Years ended December 31,
(in millions, except per award amounts)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Stock options:
 
 
 
 
 
 
 
 
 
 
 
Weighted average grant date fair value per option granted
$
7.38

 
$
7.54

 
$
7.26

 
$
7.50

 
$
7.53

 
$
7.34

Fair value of options vested
11

 
20

 
17

 
5

 
11

 
9

Cash used to purchase shares to settle options
220

 
170

 
300

 
118

 
69

 
181

Cash from participants to exercise stock options
136

 
113

 
205

 
77

 
45

 
125

Value of options exercised
84

 
57

 
95

 
41

 
24

 
56

Tax benefits from options exercised
34

 
23

 
39

 
17

 
10

 
23

Performance Shares
A target number of contingent performance shares were awarded to executives in March 2016, 2015 and 2014 and vest at December 31, 2018, 2017 and 2016, respectively. The vesting of the grants is dependent upon market and financial performance and service conditions as defined in the grants for each of the years. The number of performance shares earned from each year's grants could range from zero to twice the target number (plus additional units credited as dividend equivalents). Performance shares awarded in 2014 that are earned are settled half in cash and half in common stock, while performance shares awarded in 2016 and 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 to 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.

86



The following is a summary of the status of Edison International's nonvested performance shares:
 
Equity Awards
 
Liability Awards
 
Shares
 
Weighted-Average
Grant Date
Fair Value
 
Shares
 
Weighted-Average
Fair Value
Edison International:
 
 
 
 
 
 
 
Nonvested at December 31, 2015
57,779

 
$
61.18

 
165,629

 
$
68.44

Granted
—

 
—

 
111,754

 
 

Forfeited
(1,258
)
 
60.83

 
(13,502
)
 
 
Vested1
(56,521
)
 
61.18

 
(56,384
)
 
 

Nonvested at December 31, 2016
—

 
—

 
207,497

 
84.30

SCE:
 
 
 
 
 
 
 
Nonvested at December 31, 2015
32,463

 
$
62.01

 
90,393

 
$
68.64

Granted
—

 
—

 
50,599

 
 

Forfeited
(1,012
)
 
49.73

 
(5,751
)
 
 
Vested1
(29,080
)
 
50.75

 
(28,963
)
 
 

Affiliate transfers, net
(2,371
)
 
72.10

 
(9,611
)
 
 
Nonvested at December 31, 2016
—

 
—

 
96,667

 
84.25

1 
Relates to performance shares that will be paid in 2017 as performance targets were met at December 31, 2016.
Restricted Stock Units
Restricted stock units were awarded to Edison International's and SCE's executives in March 2016, 2015 and 2014 and vest and become payable on January 2, 2019, January 2, 2018 and January 3, 2017, respectively. Each restricted stock unit awarded includes a dividend equivalent feature and is a contractual right to receive one share of Edison International common stock, if vesting requirements are satisfied. The vesting of Edison International's restricted stock units is dependent upon continuous service through the end of the vesting period, except for awards granted to retirement-eligible participants.
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, 2015
248,143

 
$
57.89

 
134,375

 
$
58.13

Granted
123,266

 
67.42

 
55,800

 
67.37

Forfeited
(16,435
)
 
63.73

 
(7,580
)
 
61.45

Vested
(9,579
)
 
52.01

 
(8,032
)
 
56.53

Affiliate transfers, net
—

 
—

 
(13,775
)
 
62.09

Nonvested at December 31, 2016
345,395

 
61.05

 
160,788

 
60.80

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

87



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. During the year ended December 31, 2016, 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, 2016
 
$
22

Additions
 
21

Payments
 
(40
)
Balance at December 31, 2016
 
$
3

Severance costs are included in "Operation and maintenance" on the consolidated income statements.
Note 9.    Investments
Nuclear Decommissioning Trusts
Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts.
The following table sets forth amortized cost and fair value of the trust investments (see Note 4 for a discussion of fair value of the trust investments):
 
Longest
Maturity Date
 
Amortized Cost
 
Fair Value
 
 
December 31,
(in millions)
 
2016
 
2015
 
2016
 
2015
Stocks
—
 
$
319

 
$
304

 
$
1,547

 
$
1,460

Municipal bonds
2054
 
659

 
691

 
766

 
840

U.S. government and agency securities
2055
 
1,131

 
1,070

 
1,191

 
1,128

Corporate bonds
2057
 
600

 
708

 
659

 
755

Short-term investments and receivables/payables1
One-year
 
75

 
144

 
79

 
148

Total
 
 
$
2,784

 
$
2,917

 
$
4,242

 
$
4,331

1
Short-term investments include $114 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by January 4, 2017 and January 5, 2016 as of December 31, 2016 and 2015, 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 $1.5 billion and $1.4 billion at December 31, 2016 and 2015, respectively.

88



The following table sets forth a summary of changes in the fair value of the trust:
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
Balance at beginning of period
$
4,331

 
$
4,799

 
$
4,494

Gross realized gains
92

 
326

 
197

Gross realized losses
(19
)
 
(26
)
 
(5
)
Unrealized gains (losses)
44

 
(364
)
 
75

Other-than-temporary impairments
(36
)
 
(29
)
 
(14
)
Interest, dividends and other
116

 
115

 
118

Contributions
—

 
54

 
5

Income taxes
(58
)
 
(64
)
 
(62
)
Decommissioning disbursements
(224
)
 
(471
)
 
(4
)
Administrative expenses and other
(4
)
 
(9
)
 
(5
)
Balance at end of period
$
4,242

 
$
4,331

 
$
4,799

Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE. Deferred tax liabilities related to net unrealized gains at December 31, 2016 were $348 million. Accordingly, the fair value of Trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $3.9 billion at December 31, 2016. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.

Beginning in 2016, funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts.
Acquisitions
On December 31, 2015, Edison Energy acquired three businesses for an aggregate purchase price of approximately $100 million, of which $90 million was allocated to goodwill and identifiable intangibles. Under the terms of the acquisition of one of the agreements, the sellers were entitled to additional consideration (earn-out) in the event that certain financial thresholds were achieved. During the second quarter of 2016, Edison Energy entered into an agreement to buy-out this earn-out provision and recorded an after-tax charge of $13 million. The buy-out was completed, together with modification to employment contracts, in order to align long-term incentive compensation.
During 2016, a subsidiary of SoCore Energy agreed to acquire equity interests in solar garden development projects in Minnesota as part of the SunEdison bankruptcy proceedings, subject to certain conditions. The maximum purchase price is $41.9 million if all projects achieve the required conditions. SoCore Energy would also reimburse SunEdison up to $8.7 million of project-specific interconnection costs. Not all of the projects are expected to achieve the closing conditions. Through February 1, 2017, SoCore Energy acquired four of these development projects (28 MWdc) for $10.5 million.
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 2016 and 2015. 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.

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Regulatory Assets
SCE's regulatory assets included on the consolidated balance sheets are:
 
December 31,
(in millions)
2016
 
2015
Current:
 
 
 
Regulatory balancing accounts
$
135

 
$
382

Energy derivatives
150

 
159

Unamortized investments, net
49

 
—

Other
16

 
19

Total current
350

 
560

Long-term:
 
 
 
Deferred income taxes, net
4,478

 
3,757

Pensions and other postretirement benefits
710

 
849

Energy derivatives
947

 
1,027

Unamortized investments, net
80

 
182

San Onofre
857

 
1,043

Unamortized loss on reacquired debt
184

 
201

Regulatory balancing accounts
66

 
36

Environmental remediation
126

 
129

Other
7

 
288

Total long-term
7,455

 
7,512

Total regulatory assets
$
7,805


$
8,072

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 10 to 45 years.
SCE's current and long-term unamortized investments include legacy meters retired as part of the Edison SmartConnect® program. 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 2016 and 2015.
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 long-term primarily include nuclear assets related to Palo Verde. Nuclear assets related to Palo Verde are expected to be recovered by 2047 and earned a return of 7.90% in 2016 and 2015.
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% in 2016 and 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. In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. See Note 11 for further information.

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SCE's net regulatory asset related to its unamortized loss on reacquired debt will be recovered over the original amortization period of the reacquired debt over periods ranging from 10 to 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.
Regulatory Liabilities
SCE's regulatory liabilities included on the consolidated balance sheets are:
 
December 31,
(in millions)
2016
 
2015
Current:
 
 
 
Regulatory balancing accounts
$
736

 
$
1,106

Other
20

 
22

Total current
756

 
1,128

Long-term:
 
 
 
Costs of removal
2,847

 
2,781

Recoveries in excess of ARO liabilities
1,639

 
1,502

Regulatory balancing accounts
1,180

 
1,314

Other
60

 
79

Total long-term
5,726

 
5,676

Total regulatory liabilities
$
6,482

 
$
6,804

SCE's regulatory liabilities related to costs of removal represent differences between asset removal costs recorded and amounts collected in rates for those costs.
SCE's regulatory liabilities related to recoveries in excess of ARO liabilities represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 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.

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The following table summarizes the significant components of regulatory balancing accounts included in the above tables of regulatory assets and liabilities:
 
December 31,
(in millions)
2016
 
2015
Asset (liability)
 
 
 
 Energy resource recovery account
$
(20
)
 
$
(439
)
 New system generation balancing account
(6
)
 
(171
)
 Public purpose programs and energy efficiency programs
(992
)
 
(683
)
 Base revenue requirement balancing account
(426
)
 
(319
)
 Tax accounting memorandum account and pole loading
(142
)
 
(248
)
    DOE litigation memorandum account1
(122
)
 
—

 Greenhouse gas auction revenue
31

 
(75
)
 FERC balancing accounts
(69
)
 
74

 Other
31

 
(141
)
Liability
$
(1,715
)
 
$
(2,002
)
1 Represents proceeds from the Department of Energy ("DOE") resulting from its failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. Damages recovered are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs. See Note 11 for further discussion.
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, 2016, SCE had 119 renewable energy contracts.
•
QF 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 or QFs. As of December 31, 2016, SCE had 55 QF contracts.
•
Other Power Purchase Agreements – SCE has entered into 30 other power purchase agreements, including combined heat and power contracts, tolling arrangements and resource adequacy contracts.
At December 31, 2016, 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)
Renewable
Energy
Contracts
 
QF Power
Purchase
Agreements
 
Other Purchase
Agreements
2017
$
1,516

 
$
187

 
$
769

2018
1,606

 
148

 
604

2019
1,704

 
87

 
516

2020
1,776

 
39

 
472

2021
1,786

 
16

 
420

Thereafter
22,811

 
53

 
1,258

Total future commitments
$
31,199

 
$
530

 
$
4,039

The table above includes contractual obligations for power procurement contracts that met the critical contract provisions as of December 31, 2016 in which the term is over a year when it was executed. Additionally, SCE has signed contracts that have not met the critical contract provisions that would increase contractual obligations by $53 million in 2017, $235 million in

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2018, $312 million in 2019, $554 million in 2020, $630 million in 2021 and $9.1 billion thereafter, if all principal provisions are completed.
Costs incurred for power purchase agreements were $3.3 billion in 2016, $3.2 billion in 2015 and $3.8 billion in 2014, which include costs associated with contracts with terms of less than one year.
Many of the power purchase agreements that SCE entered into with independent power producers are accounted for as 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)
Operating
Leases
 
Capital
Leases
2017
$
341

 
$
1

2018
237

 
1

2019
161

 
1

2020
146

 
2

2021
142

 
2

Thereafter
1,355

 
9

Total future commitments
$
2,382

 
$
16

Amount representing executory costs
 

 
(7
)
Amount representing interest
 

 
(2
)
Net commitments
 

 
$
7

Operating lease expense for power purchase agreements was $1.9 billion in 2016, and $1.7 billion in both 2015 and
2014 (including contingent rents of $1.4 billion in 2016, $1.1 billion in 2015 and $944 million in 2014). Contingent rents for capital leases were $109 million in 2016 and less than $1 million in both 2015 and 2014. 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.
Other Lease Commitments
The following summarizes the estimated minimum future commitments for SCE's non-cancelable other operating leases (excluding SCE's power purchase agreements discussed above):
(in millions)
Operating
Leases –
Other
2017
$
52

2018
46

2019
37

2020
28

2021
22

Thereafter
258

Total future commitments
$
443

Operating lease expense for other leases (primarily related to vehicles, office space and other equipment) were $68 million in 2016, $80 million in 2015 and $96 million in 2014. 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.

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Other Commitments
The following summarizes the estimated minimum future commitments for SCE's other commitments:
(in millions)
2017
 
2018
 
2019
 
2020
 
2021
 
Thereafter
 
Total
Other contractual obligations
$
156

 
$
141

 
$
103

 
$
98

 
$
82

 
$
631

 
$
1,211

Costs incurred for other commitments were $141 million in 2016, $182 million in 2015 and $90 million in 2014. 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, 2016, 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 $3 million in 2017, $24 million in 2018, $94 million in 2019, $93 million in 2020, $71 million in 2021, and $478 million thereafter, if all principal provisions are completed.
The table above does not include asset retirement obligations, which are discussed in Note 1.
Indemnities
Edison International and SCE have various financial and performance guarantees and indemnity agreements which are issued in the normal course of business.
Edison International and SCE have 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.
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 financial position, results of operations and cash flows.
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.
San Onofre CPUC Proceedings
In November 2014, the CPUC approved the San Onofre OII Settlement Agreement, which resolved the CPUC's investigation regarding the steam generator replacement project at San Onofre and the related outages and subsequent shutdown of San Onofre. Subsequently, the San Onofre OII proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned ALJ to consider whether, in light of the Company not reporting certain ex parte communications on a timely basis, the San Onofre OII Settlement Agreement remained reasonable, consistent with the law and in the public interest, which is the standard the CPUC applies in reviewing settlements submitted for approval. In comments filed with the CPUC in July 2016, SCE asserted that the Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the OII, however, have requested that the CPUC either modify the San Onofre OII Settlement Agreement or vacate its previous approval of the settlement and reinstate the OII for further proceedings.

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In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ expressed concerns about the extent to which the failure to timely report ex parte communications had impacted the settlement negotiations and directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. The ruling set out a schedule requiring that at least two meet and confer sessions be held in the first quarter of 2017 and requiring the parties to submit a joint status report to the CPUC by April 28, 2017 if no modifications have been agreed to by some or all of the parties as a result of the meet and confer process. SCE has recorded a regulatory asset to reflect the expected recoveries under the San Onofre OII Settlement Agreement. At December 31, 2016, $857 million remains to be collected.
Challenges related to the Settlement of 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. The Ninth Circuit cancelled the oral argument that had been scheduled for February 9, 2017 and ordered the parties to notify the Ninth Circuit of the status of the San Onofre OII by May 1, 2017 and periodically thereafter.
In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its then Chief Financial Officer. The complaint 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. In September 2016, the Court granted defendants' motion to dismiss the complaint, with an opportunity for plaintiff to amend the complaint. Plaintiff filed an amended complaint and defendants again moved to dismiss the complaint in October 2016.
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 2015 and was subsequently consolidated with the July 2015 federal derivative lawsuit. In September 2016, the Court granted defendants' motion to dismiss the complaint, with an opportunity for plaintiff to amend the complaint. Plaintiff did not file an amended complaint by the required date.
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. The California state court action is currently on hold in light of the pending federal suits discussed above.
In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its 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. In July 2016, the federal court granted the defendants' motion to dismiss the lawsuit with an opportunity for the plaintiff to amend her complaint. Plaintiff filed an amended complaint in July 2016 that dismissed Edison International as a named defendant, and the remaining defendants filed a motion to dismiss in August 2016. Defendants' motion was heard by the court in November 2016 and a decision is pending.
Edison International and SCE cannot predict the outcome of these proceedings.
MHI Claims
SCE is also pursuing claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"), which designed and supplied the replacement steam generators. MHI warranted the replacement steam generators 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

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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 (San Diego Gas & Electric 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 concluded on April 29, 2016. A decision is expected to be issued in the first quarter of 2017.
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 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 MHI dispute without CPUC approval, 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 MHI dispute and the litigation costs incurred in pursuing claims against 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 that, if there is a recovery, 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 were reported in connection with these events. SCE expects to incur penalties as a result of these events. Although resolution will be subject to settlement discussions with SED and CPUC review and approval, SCE has recorded a liability for the estimated loss.
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, 2016, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites with a liability balance as of December 31, 2016, in which the upper end of the range of the costs is at least $1 million) was $128 million, including $77 million related to San Onofre. In addition to these sites, SCE also has 18 immaterial sites with a liability balance at December 31, 2016 for which the total minimum recorded liability was $3 million. Of the $131 million total environmental remediation liability for SCE, $126 million has been recorded as a regulatory asset. SCE expects to recover $46 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 $80 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

96



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 $168 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 four years are expected to range from $8 million to $20 million. Costs incurred for years ended December 31, 2016, 2015 and 2014 were $4 million, $5 million and $4 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 $13.4 billion. As of January 1, 2017, SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available ($450 million) through a Facility Form issued by American Nuclear Insurers ("ANI"). 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 the nuclear energy hazard 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 $450 million. Industry losses covered by this program could reduce limits available to SCE. Third, offsite environmental costs arising out of government orders or directives, including those issued under the Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA, are excluded, with minor exceptions from clearly identifiable accidents.
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 $52 million per year. Insurance premiums are charged to operating expense.

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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. Drought conditions in California have also increased the duration of the wildfire season and the risk of severe wildfire events. SCE has approximately $1 billion of insurance coverage for wildfire liabilities for the period ending on May 31, 2017. SCE has a self-insured retention of $10 million per wildfire occurrence. SCE or its contractors 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 or its contractors' insurance coverage.
Spent Nuclear Fuel
Under federal law, the DOE is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. Currently, both San Onofre and Palo Verde have interim storage for spent nuclear fuel on site sufficient for their current license period.
In June 2010, the United States Court of Federal Claims issued a decision granting SCE and the San Onofre co-owners damages of approximately $142 million (SCE share $112 million) to recover costs incurred through December 31, 2005 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. SCE received payment from the federal government in the amount of the damage award. In April 2016, SCE, as operating agent, settled a lawsuit on behalf of the San Onofre owners against the DOE for $162 million, including reimbursement for legal costs (SCE share $124 million) to compensate for damages caused by the DOE's failure to meet its obligation to begin accepting spent nuclear fuel for the period from January 1, 2006 to December 31, 2013. The settlement also provides for a claim submission/audit process for expenses incurred from 2014 – 2016, where SCE will submit a claim for damages caused by the DOE failure to accept spent nuclear fuel each year, followed by a government audit and payment of the claim. This process will make additional legal action to recover damages incurred in 2014 – 2016 unnecessary. The first such claim covering damages for 2014 – 2015 was filed on September 30, 2016 for approximately $56 million. In February 2017, the DOE reviewed the
2014 – 2015 claim submission and reduced the original request to approximately $43 million primarily due to DOE allocation limits. SCE has 30 days to review and accept the DOE's determination. SCE will make the claim submission for 2016 damages in the third quarter of 2017. 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, 2016, 2015 and 2014. 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.

98



Preferred stock and preference stock is:
 
Shares
Outstanding
 
Redemption
Price
 
December 31,
(in millions, except shares and per-share amounts)
 
 
2016
 
2015
Cumulative preferred stock
 
 
 
 
 
 
 
$25 par value:
 
 
 
 
 
 
 
4.08% Series
650,000

 
$
25.50

 
$
16

 
$
16

4.24% Series
1,200,000

 
25.80

 
30

 
30

4.32% Series
1,653,429

 
28.75

 
41

 
41

4.78% Series
1,296,769

 
25.80

 
33

 
33

Preference stock
 
 
 
 
 
 
 
No par value:
 
 
 
 
 
 
 
6.50% Series D (cumulative)
1,250,000

 
100.00

 
—

 
125

6.25% Series E (cumulative)
350,000

 
1,000.00

 
350

 
350

5.625% Series F (cumulative)
190,004

 
2,500.00

 
475

 
475

5.10% Series G (cumulative)
160,004

 
2,500.00

 
400

 
400

5.75% Series H (cumulative)
110,004

 
2,500.00

 
275

 
275

5.375% Series J (cumulative)
130,004

 
2,500.00

 
325

 
325

5.45% Series K (cumulative)
120,004

 
2,500.00

 
300

 
—

SCE's preferred and preference stock
 
 
 
 
2,245

 
2,070

Less issuance costs
 
 
 
 
(54
)
 
(50
)
Edison International's preferred and preference stock of utility
 

 
 

 
$
2,191

 
$
2,020

Shares of Series E preference stock issued in 2012 may be redeemed at par, in whole or in part, on or after February 1, 2022. Shares of Series F, G, H, J and K preference stock, issued in 2012, 2013, 2014, 2015 and 2016, 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, September 15, 2025 and March 15, 2026, respectively, if certain changes in tax or investment company laws occur. On or after June 15, 2017, March 15, 2018, March 15, 2024, September 15, 2025 and March 15, 2026, SCE may redeem the Series F, G, H, J and K shares, respectively, at par, in whole or in part. For shares of Series H, J and K preference stock, distributions will accrue and be payable at a floating rate from and including March 15, 2024, September 15, 2025 and March 15, 2026, respectively. Shares of Series F, G, H, J and K preference stock were issued to SCE Trust I, SCE Trust II, SCE Trust III, SCE Trust IV and SCE Trust V, respectively, special purpose entities formed to issue trust securities as discussed in Note 3. The proceeds from the sale of the shares of Series K were used to redeem $125 million of the Company's Series D preference stock and for general corporate purposes. Preference shares are not subject to mandatory redemption.
At December 31, 2016, declared dividends related to SCE's preferred and preference stock were $12 million.
Note 13.    Accumulated Other Comprehensive Loss
The changes in accumulated other comprehensive loss, net of tax, consist of:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2016
 
2015
Beginning balance
$
(56
)
 
$
(58
)
 
$
(22
)
 
$
(28
)
Pension and PBOP – net gain (loss):
 
 
 
 
 
 
 
Other comprehensive (loss) income before reclassifications
(4
)
 
(8
)
 
(2
)
 
1

Reclassified from accumulated other comprehensive loss1
6

 
10

 
3

 
5

Other
1

 
—

 
1

 
—

Change
3


2

 
2

 
6

Ending balance
$
(53
)
 
$
(56
)
 
$
(20
)
 
$
(22
)
1 
These items are included in the computation of net periodic pension and PBOP expense. See Note 8 for additional information.

99



Note 14.    Interest and Other Income and Other Expenses
Interest and other income and other expenses are as follows:
 
 
Years ended December 31,
(in millions)
 
2016
 
2015
 
2014
SCE interest and other income:
 
 
 
 
 
 
Equity allowance for funds used during construction
 
$
74

 
$
87

 
$
65

 Increase in cash surrender value of life insurance policies and life insurance benefits
 
39

 
26

 
36

Interest income
 
3

 
4

 
5

Other
 
7

 
6

 
16

Total SCE interest and other income
 
123

 
123

 
122

Other income of Edison International Parent and Other1
 
—

 
51

 
25

Total Edison International interest and other income
 
$
123

 
$
174

 
$
147

SCE other expenses:
 
 
 
 
 
 
Civic, political and related activities and donations
 
$
(32
)
 
$
(35
)
 
$
(35
)
Other
 
(12
)
 
(24
)
 
(44
)
Total SCE other expenses
 
(44
)
 
(59
)
 
(79
)
Other expense of Edison International Parent and Other
 
—

 
—

 
(1
)
Total Edison International other expenses
 
$
(44
)
 
$
(59
)
 
$
(80
)
1 Reflects Edison Capital's income related to the sale of affordable housing projects for the year ended December 31, 2015.

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 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 in September 2015 and made the remaining $214 million payment in September 2016.
Income from discontinued operations, net of tax, was $12 million (pre-tax income of $1 million), $35 million (pre-tax income of $15 million) and $185 million (pre-tax loss of $525 million) for the years ended December 31, 2016, 2015 and 2014, respectively. The 2016 and 2015 income was primarily related to the resolution of tax issues related to EME. The 2015 income also included insurance recoveries. Results from discontinued operations in 2014 consisted of a pre-tax loss of $525 million primarily related to liabilities assumed in connection with the EME Settlement Agreement, including the payments to the Reorganization Trust discussed above, and income tax benefits of $710 million related to the EME net operating loss and other credit carryforwards.

100



Note 16.    Supplemental Cash Flows Information
Supplemental cash flows information for continuing operations is:
 
Edison International
 
SCE
 
Years ended December 31,
(in millions)
2016
 
2015
 
2014
 
2016
 
2015
 
2014
Cash payments (receipts) for interest and taxes:
 
 
 
 
 
 
 
 
 
 
 
Interest, net of amounts capitalized
$
504

 
$
512

 
$
504

 
$
475

 
$
478

 
$
487

Tax payments (refunds), net
18

 
1

 
32

 
78

 
144

 
(88
)
Non-cash financing and investing activities:
 
 
 
 
 
 
 
 
 
 
 
Dividends declared but not paid:
 
 
 
 
 
 
 
 
 
 
 
Common stock
$
177

 
$
156

 
$
136

 
$
—

 
$
—

 
$
147

Preferred and preference stock
12

 
14

 
18

 
12

 
14

 
18

Details of debt exchange:
 
 
 
 
 
 
 
 
 
 
 
Pollution-control bonds redeemed (2.875%)
—

 
(203
)
 
—

 
—

 
(203
)
 
—

Pollution-control bonds issued (1.875%)
—

 
203

 
—

 
—

 
203

 
—

Notes issued under EME Settlement Agreement
$
—

 
$
—

 
$
418

 
$
—

 
$
—

 
$
—

SCE's accrued capital expenditures at December 31, 2016, 2015 and 2014 were $540 million, $543 million, and $837 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, SCE amended a power contract classified as a capital lease, which resulted in a reduction in the lease obligation 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.


101



Note 18.    Quarterly Financial Data (Unaudited)
Edison International's quarterly financial data is as follows:
 
2016
(in millions, except per-share amounts)
Total
 
Fourth
 
Third
 
Second
 
First
Operating revenue
$
11,869

 
$
2,884

 
$
3,767

 
$
2,777

 
$
2,440

Operating income
2,092

 
566

 
695

 
381

 
448

Income from continuing operations1
1,413

 
347

 
451

 
310

 
305

Income (loss) from discontinued operations, net
12

 
13

 
—

 
(2
)
 
1

Net income attributable to common shareholders1
1,311

 
329

 
421

 
280

 
281

Basic earnings (loss) per share1:
 
 
 
 
 
 
 
 
 
  Continuing operations
$
3.99

 
$
0.97

 
$
1.29

 
$
0.87

 
$
0.86

  Discontinued operations
0.03

 
0.04

 
—

 
(0.01
)
 
—

Total
$
4.02

 
$
1.01

 
$
1.29

 
$
0.86

 
$
0.86

Diluted earnings (loss) per share1:
 
 
 
 
 
 
 
 
 
  Continuing operations
$
3.94

 
$
0.96

 
$
1.27

 
$
0.86

 
$
0.85

  Discontinued operations
0.03

 
0.04

 
—

 
(0.01
)
 
—

Total
$
3.97

 
$
1.00

 
$
1.27

 
$
0.85

 
$
0.85

Dividends declared per share
1.9825

 
0.5425

 
0.4800

 
0.4800

 
0.4800

Common stock prices:
 
 
 
 
 
 
 
 
 
High
$
78.72

 
$
73.81

 
$
78.72

 
$
77.71

 
$
72.34

Low
57.97

 
67.44

 
71.31

 
67.71

 
57.97

Close
71.99

 
71.99

 
72.25

 
77.67

 
71.89

1  
Edison International adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income from continuing operations, as previously reported, was $449 million for the third quarter of 2016, $306 million for the second quarter of 2016 and $295 million for the first quarter of 2016. Net income attributable to common shareholders, as previously reported, was $419 million for the third quarter of 2016, $276 million for the second quarter of 2016 and $271 million for the first quarter of 2016. Basic EPS for continuing operations, as previously reported, was $1.29 for the third quarter of 2016, $0.86 for the second quarter of 2016 and $0.83 for the first quarter of 2016. Diluted EPS for continuing operations, as previously reported, was $1.27 for the third quarter of 2016, $0.85 for the second quarter of 2016 and $0.82 for the first quarter of 2016.

102



 
2015
(in millions, except per-share amounts)
Total
 
Fourth
 
Third
 
Second
 
First
Operating revenue
$
11,524

 
$
2,341

 
$
3,763

 
$
2,908

 
$
2,512

Operating income
2,008

 
340

 
608

 
524

 
538

Income (loss) from continuing operations1
1,082

 
(47
)
 
405

 
406

 
318

Income (loss) from discontinued operations, net
35

 
(8
)
 
43

 
—

 
—

Net income (loss) attributable to common shareholders
1,020

 
(79
)
 
421

 
379

 
299

Basic earnings (loss) per share:
 
 
 
 
 
 
 
 
 
  Continuing operations
$
3.02

 
$
(0.22
)
 
$
1.16

 
$
1.16

 
$
0.92

  Discontinued operations
0.11

 
(0.02
)
 
0.13

 
—

 
—

Total
$
3.13

 
$
(0.24
)
 
$
1.29

 
$
1.16

 
$
0.92

Diluted earnings (loss) per share:
 
 
 
 
 
 
 
 
 
  Continuing operations
$
2.99

 
$
(0.22
)
 
$
1.15

 
$
1.15

 
$
0.91

  Discontinued operations
0.11

 
(0.02
)
 
0.13

 
—

 
—

Total
$
3.10

 
$
(0.24
)
 
$
1.28

 
$
1.15

 
$
0.91

Dividends declared per share
1.7325

 
0.4800

 
0.4175

 
0.4175

 
0.4175

Common stock prices:
 
 
 
 
 
 
 
 
 
High
$
69.59

 
$
66.29

 
$
63.18

 
$
64.55

 
$
69.59

Low
55.18

 
57.51

 
55.52

 
55.18

 
61.02

Close
59.21

 
59.21

 
63.07

 
55.58

 
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.
SCE's quarterly financial data is as follows:
 
2016
(in millions)
Total
 
Fourth
 
Third
 
Second
 
First
Operating revenue
$
11,830

 
$
2,874

 
$
3,752

 
$
2,768

 
$
2,435

Operating income
2,217

 
594

 
721

 
429

 
472

Net income1
1,499

 
359

 
466

 
349

 
325

Net income available for common stock1
1,376

 
328

 
435

 
318

 
295

Common dividends declared
701

 
191

 
170

 
170

 
170

1  
SCE adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income, as previously reported, was $466 million for the third quarter of 2016, $346 million for the second quarter of 2016 and $317 million for the first quarter of 2016. Net income available for common stock, as previously reported, was $435 million for the third quarter of 2016, $315 million for the second quarter of 2016 and $287 million for the first quarter of 2016.
 
2015
(in millions)
Total
 
Fourth
 
Third
 
Second
 
First
Operating revenue
$
11,485

 
$
2,319

 
$
3,757

 
$
2,901

 
$
2,508

Operating income
2,080

 
366

 
626

 
536

 
550

Net income1
1,111

 
(51
)
 
417

 
412

 
333

Net income available for common stock
998

 
(80
)
 
389

 
384

 
305

Common dividends declared
611

 
170

 
147

 
147

 
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.
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.

103



SELECTED FINANCIAL DATA
Selected Financial Data: 2012 – 2016
(in millions, except per-share amounts)
2016
 
2015
 
2014
 
2013
 
2012
Edison International
 
 
 
 
 
 
 
 
 
Operating revenue
$
11,869

 
$
11,524

 
$
13,413

 
$
12,581

 
$
11,862

Operating expenses
9,777

 
9,516

 
10,941

 
10,866

 
9,577

Income from continuing operations
1,413

 
1,082

 
1,536

 
979

 
1,594

Income (loss) from discontinued operations, net of tax
12

 
35

 
185

 
36

 
(1,686
)
Net income (loss)
1,425

 
1,117

 
1,721

 
1,015

 
(92
)
Net income (loss) attributable to common shareholders
1,311

 
1,020

 
1,612

 
915

 
(183
)
Weighted-average shares of common stock outstanding (in millions)
326

 
326

 
326

 
326

 
326

Basic earnings (loss) per share:
 
 
 
 
 
 
 
 
 
Continuing operations
$
3.99

 
$
3.02

 
$
4.38

 
$
2.70

 
$
4.61

Discontinued operations
0.03

 
0.11

 
0.57

 
0.11

 
(5.17
)
Total
$
4.02

 
$
3.13

 
$
4.95

 
$
2.81

 
$
(0.56
)
Diluted earnings (loss) per share:
 
 
 
 
 
 
 
 
 
Continuing operations
$
3.94

 
$
2.99

 
$
4.33

 
$
2.67

 
$
4.55

Discontinued operations
0.03

 
0.11

 
0.56

 
0.11

 
(5.11
)
Total
$
3.97

 
$
3.10

 
$
4.89

 
$
2.78

 
$
(0.56
)
Dividends declared per share
1.9825

 
1.7325

 
1.4825

 
1.3675

 
1.3125

Total assets1, 2
$
51,319

 
$
50,229

 
$
49,734

 
$
46,225

 
$
44,394

Long-term debt excluding current portion
10,175

 
10,883

 
10,234

 
9,825

 
9,231

Capital lease obligations excluding current portion
6

 
7

 
196

 
203

 
210

Preferred and preference stock of utility
2,191

 
2,020

 
2,022

 
1,753

 
1,759

Common shareholders' equity
11,996

 
11,368

 
10,960

 
9,938

 
9,432

Southern California Edison Company
 
 
 
 
 
 
 
 
 
Operating revenue
$
11,830

 
$
11,485

 
$
13,380

 
$
12,562

 
$
11,851

Operating expenses
9,613

 
9,405

 
10,851

 
10,811

 
9,572

Net income
1,499

 
1,111

 
1,565

 
1,000

 
1,660

Net income available for common stock
1,376

 
998

 
1,453

 
900

 
1,569

Total assets2
$
50,891

 
$
49,795

 
$
49,456

 
$
45,786

 
$
44,034

Long-term debt excluding current portion
9,754

 
10,460

 
9,624

 
9,422

 
8,828

Capital lease obligations excluding current portion
6

 
7

 
196

 
203

 
210

Preferred and preference stock
2,245

 
2,070

 
2,070

 
1,795

 
1,795

Common shareholder's equity
12,238

 
11,602

 
11,212

 
10,343

 
9,948

Capital structure3:
 
 
 
 
 

 
 

 
 

Common shareholder's equity
50.5
%
 
48.1
%
 
49.0
%
 
48.0
%
 
48.4
%
Preferred and preference stock
9.3
%
 
8.6
%
 
9.0
%
 
8.3
%
 
8.7
%
Long-term debt
40.2
%
 
43.3
%
 
42.0
%
 
43.7
%
 
42.9
%
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.
3 This capital structure is based on the financial statements as reported under generally accepted accounting principles and does not factor in the adjustments required to calculate CPUC ratemaking capital structure.

104



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, 2016, 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, 2016. Edison International's internal control over financial reporting as of December 31, 2016 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report on the financial statements included in this report, which is incorporated herein by this reference. This annual report does not include an attestation report of SCE's independent registered public accounting firm regarding internal control over financial reporting. Management's report for SCE is not subject to attestation by the independent registered public accounting firm.
Changes in Internal Control Over Financial Reporting
There were no changes in Edison International's or SCE's internal control over financial reporting during the fourth quarter of 2016 that have materially affected, or are reasonably likely to materially affect, Edison International's or SCE's internal control over financial reporting.
Jointly Owned Utility Plant
Edison International's and SCE's respective scope of evaluation of internal control over financial reporting includes their Jointly Owned Utility Projects.
OTHER INFORMATION
None.
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

105



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 subsidiaries through the Edison Energy Group that are engaged in 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 2016, SCE's total operating revenue of $11.8 billion was derived as follows: 42.0% commercial customers, 39.6% residential customers, 3.9% industrial customers, 4.9% public authorities, 2.2% agricultural and other, and 7.4% other operating revenue.
Edison Energy Group – Energy Service Provider
Edison Energy Group is a holding company for subsidiaries engaged in pursuing competitive business opportunities across energy services and distributed solar to commercial and industrial customers. Energy services are provided through its subsidiary, Edison Energy, LLC, to help commercial and industrial customers improve managing of their energy costs and risks in dealing with increasingly complex tariff and technology choices. Solar energy solutions are provided through Edison Energy Group's subsidiary SoCore Energy and take the form of behind the meter sales of power under power purchase agreements or the sale of distributed generation systems directly to the customer (build/transfer contracts) SoCore Energy has also developed ground mounted solar projects selling power to rural cooperatives or to subscribers in community solar programs. As of December 31, 2016, SoCore Energy had constructed and achieved commercial operations for 94 MW of rooftop solar systems in 21 states. Edison Energy Group, through its subsidiary Edison Transmission, LLC, is one of the eight founders of Grid AssuranceTM, a limited liability company developing grid resiliency offerings for domestic utilities.
To date, investments in Edison Energy Group 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 electricity service obligations, shall receive first priority from the Boards of Directors of Edison International and SCE. The CPUC has also promulgated Affiliate Transaction Rules, which, among other requirements, prohibit holding companies from (1) being used as a conduit to provide non-public information to a utility's affiliate and (2) causing or abetting a utility's violation of the rules, including providing preferential treatment to affiliates.

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Employees and Labor Relations
At December 31, 2016, Edison International and its consolidated subsidiaries had an aggregate of 12,390 full-time employees, 11,947 of which were full-time employees at SCE.
Approximately 3,900 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, 2019.
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."
SCE
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 and environmental mitigation.
FERC
The FERC has the authority to regulate wholesale rates as well as other matters, including unbundled transmission service pricing, rate of return, accounting practices, and licensing of hydroelectric projects. The FERC also has jurisdiction over a portion of the retail rates and associated rate design.
CAISO
Major transmission projects required for reliability and accessing renewable resources are recommended by the California Independent System Operator ("CAISO") through a regular transmission planning process that highlights the need for and key issues associated with each project. Much of SCE’s current transmission investment program is for transmission projects that facilitate access to renewable energy resources in desert and mountain regions east and north of its load center to meet the 33% renewable mandate by 2020. The CAISO will similarly be initiating long-term transmission planning to meet the 2030 mandate for SCE to deliver 50% of its energy from qualifying renewable resources.
NERC
The FERC assigned administrative responsibility to the NERC to establish and enforce reliability standards and critical infrastructure protection standards, which protect the bulk power system against potential disruptions from cyber and physical security breaches. The critical infrastructure protection standards focus on controlling access to critical physical and cyber security assets, including supervisory control and data acquisition systems for the electric grid. Compliance with these standards is mandatory. The maximum penalty that may be levied for violating a NERC reliability or critical infrastructure protection standard is $1 million per violation, per day.
SCE has a formal cyber security 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 San Onofre and Palo Verde Nuclear Generating Stations. The NRC regulates commercial nuclear power plants through licensing, oversight and inspection, performance assessment, and enforcement of its requirements. In June 2013, SCE decided to permanently retire and decommission San Onofre. For further information, see "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" in the MD&A.

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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. The CPUC is conducting 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 develop requirements for annual reporting of risk spending and mitigation results. The risk assessment approach developed in the S-MAP will be incorporated into SCE's triennial GRC through a Risk Assessment and Mitigation Phase (RAMP), which will be initiated by November 15 in the year preceding each GRC application filing date. SCE's first RAMP will be filed in November 2018 for its 2021 GRC. The purpose of the RAMP is to provide information about the utility's assessment of its key safety risks and its proposed programs for mitigating those risks. The information developed during the RAMP will inform the utility's recommended projects and funding requests in the subsequent phase of the GRC.
SCE's 2015 GRC authorized revenue requirements for 2016 and 2017 are $5.391 billion, and $5.663 billion, respectively. In September 2016, SCE filed its 2018 GRC Application, which covers 2018 – 2020. For further discussion of the 2018 GRC, see "Management Overview—Regulatory Proceedings—2018 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 February 2017, SCE and the other Investor-Owned Utilities agreed with ORA and TURN to postpone the filing of new cost of capital applications from April 2017 to April 2019, reset the respective Investor-Owned Utilities' authorized costs of long-term debt and preferred stock, and reduce the Investor-Owned Utilities respective return on common equity, subject to CPUC approval. For more information, see "Management Overview—Regulatory Proceedings—Cost of Capital" in the MD&A.
SCE's authorized 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 and the price of energy procured 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 or price risk related to retail electricity sales.
Cost recovery balancing accounts (also referred to as cost-recovery mechanisms) are used to track and recover SCE's decoupled costs of fuel and purchased-power, as well as certain operation and maintenance expenses, including energy efficiency and demand-side management program costs. SCE earns no return on these activities and although differences between forecasted and actual costs do not impact earnings, such differences do impact cash flows and can change rapidly. SCE has other capital-related balancing accounts on which it earns a return, such as the pole loading balancing account.
SCE's balancing account for fuel and power procurement-related costs is referred to as the ERRA. 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. The trigger mechanisms allows for an expeditious rate change if the balancing account

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over- or under-collection exceeds 5% of SCE's prior year generation rate revenue. For 2017, the trigger amount is approximately $229 million. At December 31, 2016, SCE's overcollection in the ERRA was approximately $20 million, which is being refunded to customers in rates beginning on January 1, 2017.
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
Transmission capital and operating costs that are prudently incurred, including a return on its net investment in transmission assets (also referred to as "rate base"), are recovered through revenues authorized by the FERC. Since 2012, SCE has used a formula rate to determine SCE's FERC transmission revenue requirement, including its construction work in progress ("CWIP") revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. The transmission revenue requirement and rates are updated each December, to reflect a forecast of costs for the upcoming rate period, as well as a true up of the transmission revenue to actual costs incurred by SCE in the prior calendar year on its formula rate. The FERC 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. 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 two-tier residential rate structure with a separate Super User Electric (SUE) surcharge for customers consuming more than 400% of average usage. The first tier is priced at below-average cost. The second tier is priced at a higher rate per kilowatt hour, and the surcharge rate is set at more than twice the rate of Tier 1. During 2014 – 2015, the CPUC approved increases to Tier 1 and 2 rates, permitted reductions over time to the number of tiers, and set a multi-tier road map to smaller rate differentials between the tiers. By 2019, the price differential between the first and second tiers will be 25%, with the separate SUE surcharge. The CPUC has also ordered a transition beginning in 2019 from tiered to time-of-use (TOU) rates for most residential customers unless they opt to stay on the tiered rate structure. The CPUC also permits SCE to recover a larger portion of its fixed costs of serving no- or low-usage residential customers through a minimum charge of $10 per month minimum bill ($5 for low-income customers) rather than through energy charges that vary with usage. For information on residential rates for customers with renewable generation systems, see "—Competition" below.
Energy Efficiency Incentive Mechanism
Prior to September 2013, the mechanism used an incentive calculation that is based on actual energy efficiency expenditures. In September 2013, the CPUC adopted an 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 proposed ESPI schedule 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.

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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. In 2015 – 2016, SoCalGas experienced a significant natural gas fuel leak at its Aliso Canyon underground gas storage facility and the facility has not been returned to service. To date, SCE has found that increased gas-use restrictions increased the cost of electricity for customers but did not impact grid reliability. There is no certainty that these restrictions will not impact grid reliability in the future. 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, including the OII issued by the CPUC in February 2017 to consider the feasibility of minimizing or eliminating the use of the Aliso Canyon facility. SCE has also made additional procurement efforts to alleviate the impact of the partial closure of Aliso Canyon, including acceleration of existing contracts for new capacity, energy storage procurement from third-parties, contracting for design, build, transfer of utility-owned storage, additional demand response procurement, and additional energy efficiency procurement.
CAISO Wholesale Energy Market
The CAISO operates a wholesale energy market primarily in California through which competing electricity generators offer their electricity output to market participants, including electricity retailers. The CAISO schedules power in hourly increments with hourly prices through a day-ahead market in California and schedules power in fifteen-minute and five-minute increments with fifteen-minute and five-minute prices through two real-time markets that cover California and portions of six neighboring states through the Energy Imbalance Market. Both markets optimize energy procurement, ancillary service procurement, unit commitment and congestion management. SCE participates in the day-ahead and real-time markets for the sale of its own generation and generation under contract purchases for its load requirements.
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 community choice aggregators ("CCAs"). As of year-end 2016, SCE had only one CCA in its service territory (City of Lancaster) but there are several more cities and counties that are exploring the possibility of becoming CCAs in SCE's service territory. Competition between SCE and other electricity providers is conducted mainly on the basis of price.
SCE also faces increased usage of customer-owned power generation and storage alternatives, such as roof-top solar facilities and battery systems, becoming available to its customers as a result of technological developments, federal and state subsidies, and declining costs of such alternatives.
California 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.
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.

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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 under the FERC's transmission planning requirements rules, effective in 2011, that removed the incumbent public utility transmission owners' federally-based right of first refusal to construct certain new transmission facilities and mandated regional and interregional transmission planning. Regional entities, such as independent system operators, have processes for regional and interregional transmission planning and the competitive solicitation and selection of developers (including incumbent utilities) to build and own certain types of new transmission projects. In 2014, the FERC approved 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 these rules and independent service providers were selected. 
Properties
SCE supplies electricity to its customers through extensive transmission and distribution networks. Its transmission facilities, which 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 substations, all of which are located in California. SCE owns the generating facilities listed in the following table:
Generating Facility
 
Location
(in CA, unless
otherwise noted)
 
Fuel Type
 
Operator
 
SCE's
Ownership
Interest (%)
Net Physical
Capacity
(in MW)
 
SCE's Capacity
pro rata share
(in MW)
Hydroelectric Plants (33)
 
Various
 
Hydroelectric
 
SCE
 
100
%
1,153

 
 
1,153

 
Pebbly Beach Generating Station (including battery storage)
 
Catalina Island
 
Diesel/Liquid Petroleum Gas
 
SCE
 
100
%
11

1
 
11

1
Mountainview Units 3 and 4
 
Redlands
 
Natural Gas
 
SCE
 
100
%
1,050

 
 
1,050

 
Peaker Plants (3)
 
Various
 
Natural Gas
 
SCE
 
100
%
147

 
 
147

 
Enhanced Peaker Plants (2)
   (gas turbine and battery storage)
 
Various
 
Natural gas
 
SCE
 
100
%
98

2
 
98

2
Palo Verde Nuclear Generating Station
 
Phoenix, AZ
 
Nuclear
 
APS
 
15.8
%
3,739

 
 
591

 
Solar PV Plants (25)
 
Various
 
Photovoltaic
 
SCE
 
100
%
91

 
 
91

 
Fuel Cells (2)
 
Various
 
Natural Gas
 
SCE
 
100
%
2

 
 
2

 
Mira Loma Energy Storage
 
Mira Loma
 
Electricity
 
SCE
 
100
%
20

 
 
20

 
Energy Storage Projects (4)
 
Various
 
Electricity
 
SCE
 
100
%
12.4

 
 
12.4

 
Total
 
 
 
 
 
 
 
 

6,323.4

 
 
3,175.4

 
1 
Pebbly Beach Generating Station consists of 11 MW of diesel generators and liquid petroleum gas micro-turbines supported by 1 MW of battery storage capacity.
2 
Enhanced peaker plants consist of 98 MW of gas turbine supported by 20 MW of battery storage capacity.
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. 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

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and then only upon payment of specified compensation to SCE. New licenses issued to SCE are expected to contain more restrictions and obligations than the expired licenses because laws enacted since the existing licenses were issued require the FERC to give environmental objectives greater consideration in the licensing process. In addition, SCE expects additional opposition to new licenses by environmental stakeholder groups. 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
Edison International's subsidiaries are subject to regulation by federal, state, and local authorities in the United States relating to energy and the environment. These regulations impose restrictions on the operation of existing facilities, as well as the cost of mitigating the environmental impacts of past operations. 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 to meet the various environmental mandates. 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."
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. However the same regulations could potentially present opportunities to improve SCE's systems to enable the grid's role in the adoption of new energy technologies. These regulations could also contribute to the introduction of new types of electric loads as a result of the replacement of fossil fuel use in other sectors of the economy by electrification in order to achieve statewide GHG emission reductions.
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 were 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 in February 2016, the US Supreme Court blocked the implementation of the Clean Power Plan pending the completion of the judicial challenges. This action has delayed the imposition of the deadlines for the state plans discussed above. Comments made by the new federal administration indicate that further delay, or even full rescission of the Clean Power Plan is likely.  SCE cannot predict the ultimate disposition of the challenges to this regulation and therefore, cannot determine any potential compliance costs or market risks associated with its possible implementation.
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 2016 GHG emissions from utility-owned generation are estimated to be approximately 2.0 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 several 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.
Subsequently, 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 megawatt-hour, 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 of approximately 23% as weighted for the 2014 – 2016 compliance period.
Most recently, in 2016, California enacted SB 32, which requires the reduction of GHG emissions across the entire California economy to 40% below 1990 levels by 2030. Edison International expects this newest law will likely expand the focus of reductions from the generation of electricity to other large sources of GHG emissions such as the transportation and industrial sectors. Edison International believes that this change in focus will likely lead to increased electrification of these sectors. AB 197, also enacted in 2016 as a companion bill to SB 32, prioritized direct emission reductions, established joint-legislative oversight committee on climate change, and highlighted the increasing California legislative focus on disadvantaged community impacts of climate change.
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."
LEGAL PROCEEDINGS
None.

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EXECUTIVE OFFICERS OF EDISON INTERNATIONAL
Executive Officer
 
Age at
December 31, 2016
 
Company Position
Pedro J. Pizarro
 
51
 
President and Chief Executive Officer
Maria Rigatti
 
53
 
Executive Vice President and Chief Financial Officer
Adam S. Umanoff
 
57
 
Executive Vice President and General Counsel
Janet T. Clayton
 
62
 
Senior Vice President, Corporate Communications
J. Andrew Murphy
 
55
 
Senior Vice President, Strategic Planning
Gaddi H. Vasquez
 
61
 
Senior Vice President, Government Affairs
Jacqueline Trapp
 
49
 
Vice President, Human Resources
Kevin M. Payne
 
56
 
Chief Executive Officer, SCE
Ronald O. Nichols
 
63
 
President, SCE
Ronald L. Litzinger
 
57
 
President, Edison Energy Group, Inc.
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 have served in their present positions for the periods stated below. Additionally, those officers who have had other or additional principal positions in the past five years had the following business experience during that period:
Executive Officers
 
Company Position
 
Effective Dates
Pedro J. Pizarro

 
Chief Executive Officer, Edison International
President, Edison International
President, SCE
President, EME1
 
September 2016 to present
June 2016 to present
October 2014 to June 2016
January 2011 to March 2014
Maria Rigatti
 
Executive Vice President, Chief Financial Officer
Senior Vice President and Chief Financial Officer, SCE
President, Edison Mission Reorganization Trust (EME Reorg Trust)2
Senior Vice President, Chief Financial Officer, EME1
 
September 2016 to present
July 2014 to September 2016 April 2014 to June 2014
March 2011 to March 2014
Adam S. Umanoff
 
Executive Vice President and General Counsel
Edison International
Partner, Akin Gump Strauss Hauer & Feld3

 

January 2015 to present
May 2011 to December 2014

Janet T. Clayton
 
Senior Vice President, Corporate Communications,
Edison International
Senior Vice President, Corporate Communications, SCE

 

April 2011 to present
April 2013 to present

J. Andrew Murphy
 
Senior Vice President, Strategic Planning, Edison International
Senior Managing Director, Macquarie Infrastructure and Real Assets4
Executive Vice President, Strategy and M&A, NRG Energy, Inc.5

 
September 2015 to present
January 2012 to August 2015
August 2011 to November 2012

Gaddi H. Vasquez
 
Senior Vice President, Government Affairs, Edison International and SCE
Senior Vice President, Public Affairs, SCE
 

May 2013 to present
July 2009 to May 2013
Jacqueline Trapp
 
Vice President, Human Resources, Edison International and SCE
Director, Executive Talent and Rewards, Edison International
Director, Executive Development, Edison International

 
June 2016 to present
July 2012 to June 2016
June 2010 to July 2012
Kevin M. Payne
 
Chief Executive Officer, SCE
Senior Vice President, Customer Service, SCE
Vice President, Engineering and Technical Services, SCE
 
June 2016 to present
March 2014 to June 2016
September 2011 to February 2014
Ronald O. Nichols
 
President, SCE
Senior Vice President, Regulatory Affairs, SCE
General Manager/Chief Executive Officer, Los Angeles Department of Water and Power6



 
June 2016 to present
April 2014 to June 2016
January 2011 to February 2014

Ronald L. Litzinger
 
President, Edison Energy Group, Inc.
Executive Vice President, Edison International
President, SCE

 
March 2016 to present
October 2014 to March 2016
January 2011 to September 2014



114



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 was 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 
Akin Gump Strauss Hauer & Feld is a global law firm and is not a parent, affiliate or subsidiary of Edison International.
4 
Macquarie Infrastructure and Real Assets is a global infrastructure management company and is not a parent, affiliate or subsidiary of Edison International.
5 
NRG Energy, Inc. is an integrated energy company and is not a parent, affiliate or subsidiary of Edison International.
6 
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.
EXECUTIVE OFFICERS OF SOUTHERN CALIFORNIA EDISON COMPANY
Executive Officer
 
Age at
December 31, 2016
 
Company Position
Kevin M. Payne
 
56
 
Chief Executive Officer
Ronald O. Nichols
 
63
 
President
William M. Petmecky III
 
47
 
Senior Vice President and Chief Financial Officer
Russell C. Swartz
 
65
 
Senior Vice President and General Counsel
Peter T. Dietrich1
 
52
 
Senior Vice President, Transmission and Distribution
Stuart R. Hemphill
 
53
 
Senior Vice President, Customer and Operational Services
Caroline Choi
 
48
 
Senior Vice President, Regulatory Affairs
1 
Mr. Dietrich left SCE effective January 21, 2017.
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 Ronald O. 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
 
Company Position
 
Effective Dates
Kevin M. Payne
 
Chief Executive Officer, SCE
Senior Vice President, Customer Service, SCE
Vice President, Engineering and Technical Services, SCE
 
June 2016 to present
March 2014 to June 2016
September 2011 to March 2014
Ronald O. Nichols

 
President, SCE
Senior Vice President, Regulatory Affairs, SCE
General Manager/Chief Executive Officer, Los Angeles Department of Water and Power1
 
June 2016 to present
 April 2014 to June 2016
January 2011 to February 2014

William M. Petmecky III
 
Senior Vice President and Chief Financial Officer, SCE
Vice President and Treasurer, SCE
Vice President and Treasurer, EME2
 
September 2016 to present
September 2014 to September 2016
September 2011 to March 2014
Russell C. Swartz
 
Senior Vice President and General Counsel, SCE
 
February 2011 to present
Peter T. Dietrich
 
Senior Vice President, Transmission and Distribution, SCE
Chief Nuclear Officer, SCE
Senior Vice President, SCE
 
December 2013 to January 2017
December 2010 to December 2013
November 2010 to December 2013
Stuart R. Hemphill
 
Senior Vice President, Customer and Operational Services, SCE
Senior Vice President, Power Supply and Operational Services, SCE
Senior Vice President, Power Supply, SCE
 
June 2016 to present
July 2014 to June 2016
January 2011 to July 2014
Caroline Choi
 
Senior Vice President, Regulatory Affairs, SCE
Vice President Integrated Planning and Environmental Affairs, SCE

 
June 2016 to present
January 2012 to June 2016
1 
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.
2 
EME is a wholly-owned subsidiary of Edison International and an affiliate of SCE. EME filed for bankruptcy on December 17, 2012.

115



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.
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.
Equity Compensation Plans
All of Edison International's equity compensation plans that were in effect as of December 31, 2016 have been approved by security holders. The following table sets forth, for each of Edison International's equity compensation plans, the number of shares of Edison International Common Stock subject to outstanding options, warrants and rights to acquire such stock, the weighted-average exercise price of those outstanding options, warrants and rights, and the number of shares remaining available for future award grants as of December 31, 2016.
Plan Category
Number of securities to be issued upon exercise of outstanding options, warrants and rights
(a)
 
Weighted-average exercise price of outstanding options, warrants and rights
(b)
Number of securities remaining for future issuance under equity compensation plans (excluding securities reflected in column
(a)(c)
 
Equity compensation plans approved by security holders
12,112,9051
 
 
$50.26
31,986,8992
 
 
1 
This amount includes 11,544,501 shares covered by outstanding stock options, 364,921 shares covered by outstanding restricted stock unit awards, and 203,483 shares covered by outstanding deferred stock unit awards, with the outstanding shares covered by outstanding restricted stock unit and deferred stock unit awards including the crediting of dividend equivalents through December 31, 2016. The weighted-average exercise price of awards outstanding under equity compensation plans approved by security holders reflected in column (b) above is calculated based on the outstanding stock options under these plans as the other forms of awards outstanding have no exercise price. Awards payable solely in cash are not reflected in this table.
2 
This amount is the aggregate number of shares available for new awards under the Edison International 2007 Performance Incentive Plan as of December 31, 2016, and includes shares that have become available from the Edison International Equity Compensation Plan and the Edison International 2000 Equity Plan (together, the "Prior Plans"). However, no additional awards may be granted under the Prior Plans. The maximum number of shares of Edison International Common Stock that may be issued or transferred pursuant to awards under the Edison International 2007 Performance Incentive Plan is 66,000,000 shares, plus the number of any shares subject to awards issued under the Prior Plans and outstanding as of April 26, 2007 that expire, cancel or terminate without being exercised or shares being issued. Shares available under the Edison International 2007 Performance Incentive Plan may generally, subject to certain limits set forth in the plan, be used for any type of award authorized under that plan, including stock options, restricted stock, performance shares, restricted or deferred units, and stock bonuses.
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.

116



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 17, 2017.
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 2016.
Period
(a) Total
Number of Shares
(or Units)
Purchased1
 
(b) Average
Price Paid per Share (or Unit)1
 
(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
October 1, 2016 to October 31, 2016
536,660

 
 
$
71.70

 
 
—
 
—
November 1, 2016 to November 30, 2016
323,807

 
 
70.36

 
 
—
 
—
December 1, 2016 to December 31, 2016
335,279

 
 
71.43

 
 
—
 
—
Total
1,195,746

 
 
$
71.26

 
 
—
 
—
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.

117



Comparison of Five-Year Cumulative Total Return
a10k.jpg
 
 
 
 
 
 
2011

 
2012

 
2013

 
2014

 
2015

 
2016

Edison International
 
$
100

 
$
112

 
$
119

 
$
172

 
$
160

 
$
200

S & P 500 Index
 
100

 
116

 
154

 
175

 
177

 
198

Philadelphia Utility Index
 
100

 
99

 
110

 
142

 
133

 
157

Note: Assumes $100 invested on December 31, 2011 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 headings "Financial Statements and Supplementary Data" and "Exhibits and Financial Statement Schedules" in the Table of Contents of this report.
Reports of Independent Registered Public Accounting Firm
Schedule 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.

118



EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED BALANCE SHEETS
 
December 31,
(in millions)
2016
 
2015
Assets:
 
 
 
Cash and cash equivalents
$
6

 
$
7

Other current assets
261

 
259

Total current assets
267

 
266

Investments in subsidiaries
13,459

 
12,696

Deferred income taxes
646

 
626

Other long-term assets
108

 
110

Total assets
$
14,480

 
$
13,698

Liabilities and equity:
 
 
 
Short-term debt
$
539

 
$
646

Current portion of long-term debt
400

 
214

Other current liabilities
484

 
368

Total current liabilities
1,423

 
1,228

Long-term debt
397

 
398

Other long-term liabilities
664

 
704

Total equity
11,996

 
11,368

Total liabilities and equity
$
14,480

 
$
13,698


119



EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF INCOME
For the Years Ended December 31, 2016, 2015 and 2014
(in millions)
2016
 
2015
 
2014
Interest income from affiliates
$
6

 
$
3

 
$
3

Operating expenses and interest expense
86

 
78

 
94

Loss before equity in earnings of subsidiaries
(80
)
 
(75
)
 
(91
)
Equity in earnings of subsidiaries
1,337

 
1,025

 
1,482

Income before income taxes
1,257

 
950

 
1,391

Income tax benefit
(42
)
 
(35
)
 
(36
)
Income from continuing operations
1,299

 
985

 
1,427

Income from discontinued operations, net of tax
12

 
35

 
185

Net income
$
1,311

 
$
1,020

 
$
1,612


CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
For the Years Ended December 31, 2016, 2015 and 2014
(in millions)
2016
 
2015
 
2014
Net income
$
1,311

 
$
1,020

 
$
1,612

Other comprehensive income (loss), net of tax
3

 
2

 
(45
)
Comprehensive income
$
1,314

 
$
1,022

 
$
1,567



120



EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF CASH FLOWS
For the Years Ended December 31, 2016, 2015 and 2014
(in millions)
2016
 
2015
 
2014
Net cash provided by (used in) operating activities
$
493

 
$
641

 
$
(73
)
Cash flows from financing activities:
 
 
 
 
 
Long-term debt issued
400

 
—

 
—

Long-term debt issuance costs
(3
)
 
—

 
—

Payable due to affiliates
34

 
54

 
66

Short-term debt financing, net
(108
)
 
26

 
584

Settlements of stock-based compensation, net
(44
)
 
(42
)
 
(24
)
Dividends paid
(626
)
 
(544
)
 
(463
)
Net cash (used in) provided by financing activities
(347
)
 
(506
)
 
163

Capital contributions to affiliate
(147
)
 
(30
)
 
(35
)
Loans to affiliate
—

 
(106
)
 
(60
)
Net cash used in investing activities:
(147
)
 
(136
)
 
(95
)
Net decrease in cash and cash equivalents
(1
)
 
(1
)
 
(5
)
Cash and cash equivalents, beginning of year
7

 
8

 
13

Cash and cash equivalents, end of year
$
6

 
$
7

 
$
8

Note 1. Basis of Presentation
The accompanying condensed financial statements of Edison International Parent should be read in conjunction with the consolidated financial statements and notes thereto of Edison International and subsidiaries ("Registrant") included in this Form 10-K. Edison International'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 $701 million, $758 million and $378 million in 2016, 2015 and 2014, 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, 2016, SCE's 13-month weighted-average common equity component of total capitalization was 50.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $585 million, resulting in a restriction on SCE's net assets of $13.9 billion.
Note 2. Debt and Credit Agreements
Long-Term Debt
During the first quarter of 2016, Edison International Parent issued $400 million of 2.95% senior notes due in 2023. The proceeds from these bonds were used to repay commercial paper borrowings and for general corporate purposes. In addition, at December 31, 2016 and 2015, Edison International Parent had 3.75% senior notes outstanding of $400 million, which matures in 2017.

121



Credit Agreements and Short-Term Debt
During the third quarter of 2016, Edison International Parent amended the credit facility to extend the maturity date for the $1.25 billion credit facility to July 2021. At December 31, 2016, the outstanding commercial paper was $538 million at a weighted-average interest rate of 0.97%. This short-term debt was supported by the $1.25 billion multi-year revolving credit facility. At December 31, 2015, the outstanding commercial paper was $646 million at a weighted-average interest rate of 0.78%.
The following table summarizes the status of the credit facility at December 31, 2016:
(in millions)
 
Commitment
$
1,250

Outstanding borrowings
(538
)
Amount available
$
712

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. At December 31, 2016, Edison International's consolidated debt to total capitalization ratio was 0.47 to 1.
Note 3. Related-Party Transactions
Edison International's Parent expense from services provided by SCE was $3 million annually in 2016, 2015 and 2014. Edison International's Parent interest expense from loans due to affiliates was $3 million in 2016, $6 million in 2015 and $1 million in 2014. Edison International Parent had current related-party receivables of $262 million and $252 million and current related-party payables of $221 million and $149 million at December 31, 2016 and 2015, respectively. Edison International Parent had long-term related-party receivables of $103 million and $105 million at December 31, 2016 and 2015, respectively, and long-term related-party payables of $243 million and $213 million at December 31, 2016 and 2015, 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."

122



EDISON INTERNATIONAL
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
 
 
 
Additions
 
 
 
 
(in millions)
Balance at
Beginning of
Period
 
Charged to
Costs and
Expenses
 
Charged to
Other
Accounts
 
Deductions
 
Balance at
End of
Period
For the Year ended December 31, 2016
 
 
 
 
 
 
 
 
 
Allowance for uncollectible accounts
 
 
 
 
 
 
 
 
 
Customers
$
46.2

 
$
17.7

 
$
—

 
$
22.7

 
$
41.2

All others
15.5

 
15.9

 
—

 
10.8

 
20.6

Total allowance for uncollectible amounts
$
61.7

 
$
33.6

 
$
—

 
$
33.5

a 
$
61.8

Tax valuation allowance
$
32.0

 
$
—

 
$
—

 
$
8.0

d 
$
24.0


 
 
 
 
 
 
 
 
 
For the Year ended December 31, 2015
 
 
 
 
 
 
 
 
 
Allowance for uncollectible accounts
 
 
 
 
 
 
 
 
 
Customers
$
48.9

 
$
23.9

 
$
—

 
$
26.6

 
$
46.2

All others
23.3

 
18.0

 
—

 
25.8

 
15.5

Total allowance for uncollectible amounts
$
72.2

 
$
41.9

 
$
—

 
$
52.4

a 
$
61.7

Tax valuation allowance
$
29.0

 
$
3.0

 
$
—

 
$
—

 
$
32.0


 
 
 
 
 
 
 
 
 
For the Year ended December 31, 2014
 
 
 
 
 
 
 
 
 
Allowance for uncollectible accounts
 
 
 
 
 
 
 
 
 
Customers
$
52.2

 
$
24.1

 
$
—

 
$
27.4

 
$
48.9

All others
17.8

 
19.7

 
—

 
14.2

 
23.3

Total allowance for uncollectible amounts
$
70.0

 
$
43.8

 
$
—

 
$
41.6

a 
$
72.2

Tax valuation allowance
$
1,380.0

b 
$
—

 
$
—

 
$
1,351.0

c 
$
29.0

a 
Accounts written off, net.
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.
d 
In 2016, Edison International determined that $8 million of the assets subject to a valuation allowance, had no expectation of recovery and were written off.

123



SOUTHERN CALIFORNIA EDISON COMPANY
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
 
 
 
Additions
 
 
 
 
(in millions)
Balance at
Beginning of
Period
 
Charged to
Costs and
Expenses
 
Charged to
Other
Accounts
 
Deductions
 
Balance at
End of
Period
For the Year ended December 31, 2016
 
 
 
 
 
 
 
 
 
For the Year ended
 
 
 
 
 
 
 
 
 
Customers
$
46.2

 
$
17.0

 
$
—

 
$
22.7

 
$
40.5

All others
15.5

 
15.9

 
—

 
10.8

 
20.6

Total allowance for uncollectible accounts
$
61.7

 
$
32.9

 
$
—

 
$
33.5

a 
$
61.1

 
 
 
 
 
 
 
 
 
 
For the Year ended December 31, 2015
 
 
 
 
 
 
 
 
 
Allowance for uncollectible accounts
 
 
 
 
 
 
 
 
 
Customers
$
48.9

 
$
23.9

 
$
—

 
$
26.6

 
$
46.2

All others
18.7

 
18.0

 
—

 
21.2

 
15.5

Total allowance for uncollectible accounts
$
67.6

 
$
41.9

 
$
—

 
$
47.8

a 
$
61.7

 
 
 
 
 
 
 
 
 
 
For the Year ended December 31, 2014
 
 
 
 
 
 
 
 
 
Allowance for uncollectible accounts
 
 
 
 
 
 
 
 
 
Customers
$
52.2

 
$
24.1

 
$
—

 
$
27.4

 
$
48.9

All others
13.3

 
19.6

 
—

 
14.2

 
18.7

Total allowance for uncollectible accounts
$
65.5

 
$
43.7

 
$
—

 
$
41.6

a 
$
67.6

a 
Accounts written off, net.


124



SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.
 
EDISON INTERNATIONAL
 
 
SOUTHERN CALIFORNIA EDISON COMPANY
 
 
 
 
 
By:
/s/ Aaron D. Moss
 
By:
/s/ Connie J. Erickson
 
 
 
 
 
 
Aaron D. Moss
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 21, 2017
 
Date:
February 21, 2017

125



Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrants and in the capacities and on the date indicated.
Signature
 
Title
 
 
 
A. Principal Executive Officers
 
 
 
 
 
Pedro J. Pizarro*
 
President,
Chief Executive Officer and Director
(Edison International)
 
 
 
Kevin Payne*
 
Chief Executive Officer and SCE Director (Southern California Edison Company)
 
 
 
B. Principal Financial Officers
 
 
 
 
 
Maria Rigatti*
 
Executive Vice President and Chief Financial Officer
(Edison International)
 
 
 
William M. Petmecky III*
 
Senior Vice President and Chief Financial Officer
(Southern California Edison Company)
 
 
 
C. Principal Accounting Officers
 
 
 
 
 
Aaron D. Moss
 
Vice President and Controller
(Edison International)
 
 
 
Connie J. Erickson
 
Vice President and Controller
(Southern California Edison Company)
 
 
 
D. Directors (Edison International and Southern California Edison Company, unless otherwise noted)
 
 
 
 
 
Jagjeet S. Bindra*
 
Director
 
 
 
Vanessa C.L. Chang*
 
Director
 
 
 
Louis Hernandez, Jr.*
 
Director
James T. Morris*
 
Director
Pedro J. Pizarro*
 
Director
 
 
 
Kevin Payne (SCE only)*
 
Director
 
 
 
Richard T. Schlosberg, III*
 
Director
 
 
 
Linda G. Stuntz*
 
Director
 
 
 
William P. Sullivan*
 
Chair of the Board and Director
 
 
 
Ellen O. Tauscher*
 
Director
 
 
 
Peter J. Taylor*
 
Director
 
 
 
Brett White*
 
Director
 
 
 
 
 
 
 
 
*By:
/s/ Aaron D. Moss
*By:
/s/ Connie J. Erickson
 
 
 
 
 
Aaron D. Moss
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 21, 2017
Date:
February 21, 2017

126



EXHIBIT INDEX
Exhibit
Number
 
Description
 
 
 
Edison International
 
 
 
3.1
 
Certificate of Restated Articles of Incorporation of Edison International, effective December 19, 2006 (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2006)*
 
 
 
3.2
 
Bylaws of Edison International, as amended October 27, 2016 (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-Q dated November 1, 2016 and filed November 1, 2016)*
 
 
 
Southern California Edison Company
 
 
 
3.3
 
Restated Articles of Incorporation of Southern California Edison Company, effective March 2, 2006, together with all Certificates of Determination of Preference Stock issued since March 2, 2006 (File No. 1-2313 filed as Exhibit 3.1 to Southern California Edison Company's Form 10-Q for the quarter ended March 31, 2016)*
 
 
 
3.4
 
Bylaws of Southern California Edison Company, as amended October 27, 2016 (File No. 1-2313, filed as Exhibit 3.2 to Southern California Edison Company's Form 10-Q dated November 1, 2016 and filed November 1, 2016)*
 
 
 
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
 
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)*
4.3
 
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**
 
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)*
 
 
 
10.2**
 
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)*
 
 
 
10.3**
 
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)*
 
 
 
10.3.1**
 
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)*
 
 
 
10.3.2**
 
Executive and Director Grantor Trust Agreements Amendment 2008-1 (File No. 1-9936, filed as Exhibit No. 10.6.2 to Edison International's Form 10-K for the year ended December 31, 2008)*
 
 
 
10.4**
 
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)*
 
 
 
10.5**
 
Edison International 2008 Executive Deferred Compensation Plan, as amended and restated effective December 9, 2015* (File No. 1-9936, filed as Exhibit No. 10.5 to Edison International's Form 10-K for the year ended December 31, 2015)*
 
 
 
10.6**
 
Executive Grantor Trust Agreement, dated August 1995 (File No. 1-9936, filed as Exhibit 10.12 to Edison International's Form 10-K for the year ended December 31, 1995)*
10.6.1**
 
Executive Grantor Trust Agreement Amendment 2002-1, effective May 14, 2002 (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended June 30, 2002)*
 
 
 
10.7**
 
Southern California Edison Company Executive Supplemental Benefit Program, as amended effective August 24, 2016 (File No. 1-9936, filed as Exhibit No. 10.3 for the quarter ended September 30, 2016)*
 
 
 
10.8**
 
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 August 24, 2016 (File No. 1-9936, filed as Exhibit No. 10.1 to Edison International's Form 10-Q for the quarter ended September 30, 2016)*
 
 
 

127



Exhibit
Number
 
Description
10.9**
 
Edison International Executive Incentive Compensation Plan, as amended and restated effective August 24, 2016 (File No. 1-9936, filed as Exhibit No. 10.2 to Edison International's Form 10-Q for the quarter ended September 30, 2016)*
 
 
 
10.10**
 
Edison International 2008 Executive Disability Plan, as amended and restated effective January 1, 2016 (File No. 1-9936, filed as Exhibit No. 10.2 to Edison International's Form 10-Q for the quarter ended March 31, 2016)*
 
 
 
10.11**
 
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* (File No. 1-9936, filed as Exhibit No. 10.11.1 to Edison International's Form 10-K for the year ended December 31, 2015)*
 
 
 
10.12**
 
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)*
 
 
 
10.13**
 
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**
 
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)*
 
 
 
10.15**
 
Edison International 2007 Performance Incentive Plan as amended and restated effective May 2, 2016 (File No. 1-9936, filed as Exhibit 10.1 to the Edison International Form 10-Q for the quarter ended June 30, 2016)*
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)*
10.15.9**
 
Edison International 2016 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended March 31, 2016)*

 
 
 
 
 
 
10.16**
 
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)*
 
 
 
10.16.1**
 
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)*
 
 
 
10.17**
 
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)*
 
 
 

128



Exhibit
Number
 
Description
10.18**
 
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)*
 
 
 
10.18.1**
 
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)*
 
 
 
10.19**
 
Edison International 2008 Executive Severance Plan, as amended and restated effective August 24, 2016 (File No. 1-9936, filed as Exhibit 10.5 for the quarter ended September 30, 2016)*
 
 
 
10.20**
 
Edison International and Southern California Edison Company Director Compensation Schedule, as adopted August 25, 2016 (File No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended September 30, 2016)*
 
 
 
10.21**
 
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*
 
 
 
10.22**
 
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)*
 
 
 
10.23
 
Amended and Restated Agreement for the Allocation of Income Tax Liabilities and Benefits among Edison International, Southern California Edison Company and The Mission Group dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*
 
 
 
10.23.1
 
Amended and Restated Tax-Allocation Agreement among The Mission Group and its first-tier subsidiaries dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3.1 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*
 
 
 
10.23.2
 
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)*
 
 
 
10.23.3
 
Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.11 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*
 
 
 
10.23.4
 
Modification No. 1 to the Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.1 to Edison Mission Energy's Form 8-K dated November 15, 2012 and filed November 21, 2012)*
 
 
 
10.23.5
 
Amended and Restated Administrative Agreement Re Tax Allocation Payments, dated February 13, 2012, among Edison International and subsidiary parties. (File No. 333-68630, filed as Exhibit 10.12 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*
 
 
 
10.24**
 
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)*
 
 
 
10.25**
 
Edison International 2016 Executive Annual Incentive Program (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended March 31, 2016)*
 
 
 
10.26**
 
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
 
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)*
 
 
 
10.28
 
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)*
10.29
 
Term Loan Credit Agreement, dated as of January 13, 2017, among Southern California Edison Company, the several banks and other financial institutions from time to time parties thereto, and Wells Fargo Bank, N.A., as administrative agent for the lenders (File 1-2313, filed as Exhibit 10.1 to Southern California Edison Company's Form 8-K dated January 13, 2017 and filed January 13, 2017)*
 
 
 

129



Exhibit
Number
 
Description
10.30
 
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)*
 
 
 
21
 
Subsidiaries of the Registrants
 
 
 
23.1
 
Consent of Independent Registered Public Accounting Firm (Edison International)
 
 
 
23.2
 
Consent of Independent Registered Public Accounting Firm (Southern California Edison Company)
 
 
 
24.1
 
Powers of Attorney of Edison International and Southern California Edison Company
 
 
 
24.2
 
Certified copies of Resolutions of Boards of Edison International and Southern California Edison Company Directors Authorizing Execution of SEC Reports
 
 
 
31.1
 
Certifications of the Chief Executive Officer and Chief Financial Officer of Edison International pursuant to Section 302 of the Sarbanes-Oxley Act
 
 
 
31.2
 
Certifications of the Chief Executive Officer and Chief Financial Officer of Southern California Edison Company pursuant to Section 302 of the Sarbanes-Oxley Act
 
 
 
32.1
 
Certifications of the Chief Executive Officer and the Chief Financial Officer of Edison International required by Section 906 of the Sarbanes-Oxley Act
 
 
 
32.2
 
Certifications of the Chief Executive Officer and the Chief Financial Officer of Southern California Edison Company required by Section 906 of the Sarbanes-Oxley Act
 
 
 
101.1
 
Financial statements from the annual report on Form 10-K of Edison International for the year ended December 31, 2016, filed on February 21, 2017, 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
 
 
 
101.2
 
Financial statements from the annual report on Form 10-K of Southern California Edison Company for the year ended December 31, 2016, filed on February 21, 2017, 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).

130