10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)
þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended March 31, 2017
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)

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 oSouthern California Edison Company    Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T 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 oSouthern California Edison Company    Yes þ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-12 of the Exchange Act. (Check One):
Edison International	Large Accelerated Filer þ	Accelerated Filer ¨	Non-accelerated Filer ¨	Smaller Reporting Company ¨	Emerging growth company ¨
Southern California Edison Company	Large Accelerated Filer ¨	Accelerated Filer ¨	Non-accelerated Filer þ	Smaller Reporting Company ¨	Emerging growth company ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Edison International	¨	Southern California Edison Company	¨

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

Edison International        Yes ¨ No þSouthern California Edison Company    Yes ¨ No þ

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

Common Stock outstanding as of April 28, 2017:
Edison International	325,811,206 shares
Southern California Edison Company	434,888,104 shares

TABLE OF CONTENTS

					SEC Form 10-Q Reference Number
GLOSSARY				iii
FORWARD-LOOKING STATEMENTS				1
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS				3	Part I, Item 2
	MANAGEMENT OVERVIEW			3
		Highlights of Operating Results		3
		Capital Program		4
		Regulatory Proceedings		4
	RESULTS OF OPERATIONS			5
	Southern California Edison Company			5
		Three months ended March 31, 2017 versus March 31, 2016		5
			Earning Activities	6
			Cost-Recovery Activities	6
	Supplemental Operating Revenue Information			6
	Income Taxes			7
	Edison International Parent and Other			7
		Income from Continuing Operations		7
		Strategic Review of Edison Energy Group Competitive Businesses		7
	LIQUIDITY AND CAPITAL RESOURCES			7
	Southern California Edison Company			7
		Available Liquidity		8
		Capital Investment Plan		8
		Dividend Restrictions		8
		Margin and Collateral Deposits		9
	Edison International Parent and Other			9
	Historical Cash Flows			9
		Southern California Edison Company		9
		Edison International Parent and Other		12
	Contingencies			13
	MARKET RISK EXPOSURES			13
	Commodity Price Risk			13
	Credit Risk			13
	CRITICAL ACCOUNTING ESTIMATES AND POLICIES			13
	NEW ACCOUNTING GUIDANCE			13
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK				13	Part I, Item 3
FINANCIAL STATEMENTS				14	Part I, Item 1
	Edison International Consolidated Statements of Income			14
	Edison International Consolidated Statements of Comprehensive Income			15
	Edison International Consolidated Balance Sheets			16
	Edison International Consolidated Statements of Cash Flows			18
	SCE Consolidated Statements of Income			19

i

	SCE Consolidated Statements of Comprehensive Income		19
	SCE Consolidated Balance Sheets		20
	SCE Consolidated Statements of Cash Flows		22
	NOTES TO CONSOLIDATED FINANCIAL STATEMENTS		23
		Note 1. Summary of Significant Accounting Policies	23
		Note 2. Consolidated Statements of Changes in Equity	25
		Note 3. Variable Interest Entities	27
		Note 4. Fair Value Measurements	29
		Note 5. Debt and Credit Agreements	32
		Note 6. Derivative Instruments	33
		Note 7. Income Taxes	35
		Note 8. Compensation and Benefit Plans	36
		Note 9. Investments	37
		Note 10. Regulatory Assets and Liabilities	38
		Note 11. Commitments and Contingencies	39
		Note 12. Accumulated Other Comprehensive Loss	43
		Note 13. Interest and Other Income and Other Expenses	44
		Note 14. Supplemental Cash Flows Information	44
CONTROLS AND PROCEDURES			44	Part I, Item 4
	Disclosure Controls and Procedures		44
	Changes in Internal Control Over Financial Reporting		45
	Jointly Owned Utility Plant		45
LEGAL PROCEEDINGS			45	Part II, Item 1
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS			45	Part II, Item 2
	Purchases of Equity Securities by Edison International and Affiliated Purchasers		45
EXHIBITS			46	Part II, Item 6
SIGNATURES			47

This is a combined Form 10-Q 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.

ii

GLOSSARY

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

2016 Form 10-K	Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 2016
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
DERs	distributed energy resources
DOE	U.S. Department of Energy
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
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 used in the United States
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)

iii

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 SCE, 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

iv

FORWARD-LOOKING STATEMENTS

This quarterly report on Form 10-Q 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, the 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 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 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;

• the outcome of the strategic review of Edison Energy Group, which may include changes to existing competitive business models and/or exit of certain business activities;

• 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, Western Electricity Coordination Council, 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.

Additional information about risks and uncertainties, including more detail about the factors described in this report, is contained throughout this report and in the 2016 Form 10-K, including the "Risk Factors" section. Readers are urged to read this entire report, including information incorporated by reference, as well as the 2016 Form 10-K, and carefully consider the risks, uncertainties, and other factors that affect Edison International's and SCE's businesses. Forward-looking statements speak only as of the date they are made and neither Edison International nor SCE are obligated to publicly update or revise forward-looking statements. Readers should review future reports filed by Edison International and SCE with the SEC. Edison International and SCE 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. Edison International and SCE also routinely post or provide direct links to presentations, documents and other information that may be of interest to investors at www.edisoninvestor.com (Events and Presentations) in order to publicly disseminate such information.

The MD&A for the three months ended March 31, 2017 discusses material changes in the consolidated financial condition, results of operations and other developments of Edison International and SCE since December 31, 2016, and as compared to the three months ended March 31, 2016. This discussion presumes that the reader has read or has access to Edison International's and SCE's MD&A for the calendar year 2016 (the "year-ended 2016 MD&A"), which was included in the 2016 Form 10-K.

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 pursing 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 report relates to both filers.

	Three months ended March 31,
(in millions)	2017		20161			Change
Net income (loss) attributable to Edison International
Continuing operations
SCE	$	349	$	295		$	54
Edison International Parent and Other	13		(15		)	28
Discontinued operations	—		1			(1		)
Edison International	362		281			81
Less: Non-core items
SCE	—		—			—
Edison International Parent and Other	—		2			(2		)
Discontinued operations	—		1			(1		)
Total non-core items	—		3			(3		)
Core earnings (losses)
SCE	349		295			54
Edison International Parent and Other	13		(17		)	30
Edison International	$	362	$	278		$	84

¹ First quarter 2016 earnings were updated to reflect the implementation of the accounting standard for share-based payments effective January 1, 2016. See "Notes to Consolidated Financial Statements—Note 1" for further information.

Edison International's earnings are prepared in accordance with GAAP. 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 investors 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 first quarter 2017 earnings increased $81 million from the first quarter of 2016, comprised of an increase in SCE's earnings of $54 million, an increase in Edison International Parent and Other earnings of $28 million, and a decrease in income from discontinued operations of $1 million. SCE's increase in earnings was due to an increase in revenue from the escalation mechanism set forth in the 2015 GRC decision, lower operation and maintenance expenses and higher income tax benefits partially offset by higher net financing costs. Edison International Parent and Other increase in net income was due to higher core earnings of $30 million and $2 million of lower non-core earnings. The increase in core earnings was due to higher income tax benefits related to stock option exercises.

3

Capital Program

Total capital expenditures (including accruals) were $647 million and $729 million for the first three months of 2017 and 2016, respectively. In the year-ended 2016 MD&A, SCE projected 2017 capital expenditures of approximately $4.2 billion. Those expenditures included $182 million of grid modernization capital spending that will promote increased safety and reliability and will 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. SCE currently projects 2017 capital expenditures of $4.0 billion, reflecting the lack of approval of a grid modernization memorandum account and minor delays on the start of construction for the Mesa Substation Project. Actual capital spending may be affected by: changes in regulatory, environmental and engineering design requirements; permitting and project delays; cost and availability of labor, equipment, and materials; and other factors. For further information regarding the capital program see "Liquidity and Capital Resources—Capital Investment Plan" and the year-ended 2016 MD&A, "Management Overview—Capital Program."

Regulatory Proceedings

2018 General Rate Case

As discussed in the year-ended 2016 MD&A, 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 April 2017, ORA recommended that SCE's requested 2018 base revenue requirement be decreased by approximately $208 million, comprised of approximately $164 million in operations and maintenance expense reductions and approximately $44 million in capital-related revenue requirement reductions largely related to the proposed reduction of 100% of grid modernization capital spending. ORA proposed capturing grid modernization spending in a memorandum account for review in the 2021 GRC if any spending is authorized by the CPUC. Testimony from other parties related to SCE's 2018 GRC application is due in May 2017.

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.

MHI Claims

In March 2017, SCE received a decision from the International Chamber of Commerce International Court of Arbitration on claims against MHI regarding failure of the replacement steam generators that MHI supplied for San Onofre. The net recovery awarded to SCE was initially determined to be $52 million. An adjustment to the interest awarded to SCE subsequently reduced the net recovery to $47 million. SCE has determined that it will not appeal the decision. As a result of uncertainty associated with the allocation of the award under the San Onofre OII Settlement Agreement, SCE recorded a regulatory liability for the net recovery.

For more information on the challenges to the settlement of the San Onofre OII and the arbitration tribunal decision on MHI, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."

4

Cost of Capital

In April 2017, the CPUC issued a proposed decision that would have adopted the petition previously filed by SCE, Pacific Gas & Electric Company, SDG&E, and SoCalGas (collectively, the "Investor-Owned Utilities"), ORA, and TURN to modify the prior CPUC decisions addressing the Investor-Owned Utilities' costs of capital. The decision, if adopted by the CPUC, would have established SCE's authorized ROE at 10.30%, beginning January 1, 2018. Subsequently in April 2017, the CPUC withdrew the proposed decision from the agenda of its April 27 meeting. Timing for additional action on the settling parties’ petition has not been defined. For more information on the terms of the settling parties' petition, see "Management Overview—Regulatory Proceedings" in the year-ended 2016 MD&A.

RESULTS OF OPERATIONS

Southern California Edison Company

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.

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

Three months ended March 31, 2017 versus March 31, 2016

	Three months ended March 31, 2017								Three months ended March 31, 2016
(in millions)	Earning Activities			Cost- Recovery Activities		Total Consolidated			Earning Activities			Cost- Recovery Activities		Total Consolidated
Operating revenue	$	1,552		$	904	$	2,456		$	1,522		$	913	$	2,435
Purchased power and fuel	—			784		784			—			794		794
Operation and maintenance	451			120		571			484			119		603
Depreciation, decommissioning and amortization	497			—		497			475			—		475
Property and other taxes	97			—		97			91			—		91
Total operating expenses	1,045			904		1,949			1,050			913		1,963
Operating income	507			—		507			472			—		472
Interest expense	(141		)	—		(141		)	(131		)	—		(131		)
Other income and expenses	26			—		26			26			—		26
Income before income taxes	392			—		392			367			—		367
Income tax expense	12			—		12			42			—		42
Net income	380			—		380			325			—		325
Preferred and preference stock dividend requirements	31			—		31			30			—		30
Net income available for common stock	$	349		$	—	$	349		$	295		$	—	$	295
Net income available for common stock						$	349							$	295
Less:
Non-core earnings						—								—
Core earnings1						$	349							$	295

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

5

Earning Activities

Earning activities were primarily affected by the following:

• Higher operating revenue of $30 million primarily due to the following:

• An increase in CPUC revenue of approximately $59 million primarily due to the escalation mechanism as set forth in the 2015 GRC decision.

• An increase in revenue of approximately $31 million resulting from lower 2017 incremental tax benefits recognized through the tax accounting memorandum account ("TAMA") and the pole loading balancing account (offset in income taxes as discussed below).

• The receipt of the MHI arbitration decision triggered a tax deduction for the abandonment of San Onofre. As a result, SCE recorded a decrease in CPUC revenue of approximately $65 million (offset in income taxes as discussed below) which will be credited to customers. See "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for further information.

• Lower operation and maintenance costs of $33 million primarily due to the impact of SCE's operational and service excellence initiatives as well as lower storm-related activities.

• Higher depreciation, decommissioning, and amortization expense of $22 million primarily related to depreciation on transmission and distribution investments.

• Higher interest expense of $10 million primarily due to increased borrowings.

• Lower income taxes of $30 million primarily due to the following:

• Higher income tax benefits of $39 million related to a tax deduction for the abandonment of San Onofre (offset with revenue above).

• Lower tax expense of $10 million related to the settlement of open tax positions with the IRS for taxable years 2007 through 2012.

• Lower income tax benefits of $18 million related to incremental tax benefits for TAMA and the pole loading balancing accounts (offset in revenue above) partially offset by higher income tax benefits in 2017 on other property-related items, including cost of removal and depreciation deductions.

• Higher pre-tax income for the first quarter of 2017, as discussed above.

Cost-Recovery Activities

Cost-recovery activities were primarily affected by the following:

• Lower purchased power and fuel costs of $10 million primarily driven by lower realized losses on hedging activities ($2 million in 2017 compared to $27 million in 2016) partially offset by higher power and gas prices experienced in 2017 relative to 2016.

Supplemental Operating Revenue Information

SCE's retail billed and unbilled revenue (excluding wholesale sales and balancing account overcollections/undercollections) was $2.4 billion for both the three months ended March 31, 2017 and 2016.

Retail billed and unbilled revenue for the three months ended March 31, 2017 reflects a rate increase of $113 million and a sales volume decrease of $79 million. The rate increase was due to implementation of the 2017 ERRA rate increase. The sales volume decrease was due to unseasonably warm weather experienced in the first quarter of 2016.

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" in the 2016 Form 10-K).

6

Income Taxes

SCE's income tax expense decreased by $30 million for the three months ended March 31, 2017 compared to the same period in 2016.

The effective tax rates were 3.1% and 11.4% for the three months ended March 31, 2017 and 2016, respectively. SCE's effective tax rate is lower than the statutory rate 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 is primarily related to the ratemaking treatment on the San Onofre tax abandonment.

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.

Edison International Parent and Other

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

Income from Continuing Operations

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

	Three months ended March 31,
(in millions)	2017			2016
Edison Energy Group and subsidiaries1	$	(6	)	$	(6	)
Edison Mission Group and subsidiaries	(1		)	—
Corporate expenses and other2	20			(9		)
Total Edison International Parent and Other	$	13		$	(15	)

¹   Includes incomeof less than $1 million and $2 million for the three months ended March 31, 2017 and 2016, respectively, related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method.

²  Includes interest expense (pre-tax) of $10 million and $8 million for the three months ended March 31, 2017 and 2016, respectively.

The income from continuing operations of Edison International Parent and Other was $13 million for the three months ended March 31, 2017 compared to a loss of $15 million for the same period in 2016. The increase in income for the first three months of 2017 was primarily due to higher income tax benefits related to stock option exercises ($35 million and $2 million for the three months ended March 31, 2017 and 2016, respectively).

Strategic Review of Edison Energy Group Competitive Businesses

Edison International is performing a strategic review of the competitive businesses pursued by subsidiaries of Edison Energy Group. Competitive businesses include energy services provided by Edison Energy and distributed solar solutions provided by SoCore Energy. The outcome of the strategic review may affect Edison International's ability to fully recover its investments in these businesses. Edison International's investments in SoCore Energy and Edison Energy were $195 million and $103 million, respectively, as of March 31, 2017.

LIQUIDITY AND CAPITAL RESOURCES

Southern California Edison Company

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 and 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, as needed. SCE also has availability under its credit facilities to fund liquidity requirements.

7

Available Liquidity

At March 31, 2017, SCE had approximately $2.66 billion available under its $2.75 billion multi-year revolving credit facility. In January 2017, SCE borrowed $300 million under a Term Loan Agreement and reissued $135 million of pollution control bonds. In March 2017, SCE issued $700 million of first and refunding mortgage bonds. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."

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 March 31, 2017, SCE's debt to total capitalization ratio was 0.44 to 1.

At March 31, 2017, SCE was in compliance with all other financial covenants that affect access to capital.

Capital Investment Plan

Below are updates for large transmission and substation projects since the filing of the 2016 Form 10-K. SCE is currently evaluating the timing of its major construction projects. For further information on these projects, see "Liquidity and Capital Resources—SCE—Capital Investment Plan—Major Transmission Projects" in the year-end 2016 MD&A.

Major Transmission Projects

West of Devers

In March 2017, the CPUC issued a decision denying ORA's September 2016 Application for Rehearing regarding the West of Devers Upgrade Project which sought additional project modifications and environmental mitigation measures. This action confirmed SCE's proposed project, which is on track to be placed in service in 2021.

Mesa Substation

In February 2017, the CPUC issued a final decision approving the Mesa Substation Project largely consistent with SCE's proposed project and rejected alternative project configurations proposed by CPUC staff. Timing of the CPUC approval and preconstruction requirements for obtaining other permits and approvals have delayed the start of construction. As a result, SCE has revised the projected in-service date to 2022.

Alberhill System

In April 2017, the CPUC issued a final environmental impact report for the Alberhill System. This report rejected different alternatives recommended by CPUC staff and intervenors, selecting SCE's proposed project as the environmentally superior project. A final CPUC decision is anticipated by the end of 2017.

Coolwater-Lugo

In February 2017, the FERC approved a settlement allowing SCE to recover 100% of the requested $37.1 million of costs incurred by SCE related to the cancelled Coolwater-Lugo transmission project.

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 March 31, 2017, 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 $603 million, resulting in a restriction on net assets of approximately $14.0 billion.

In the first quarter of 2017, SCE declared and paid a dividend to Edison International of $191 million. Future dividend amounts and timing of distributions are dependent on a number of factors including the level of capital expenditures, operating cash flows and earnings.

8

Margin and Collateral Deposits

Certain derivative instruments, power contracts and other contractual arrangements contain collateral requirements. Future collateral requirements may differ from the requirements at March 31, 2017, 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 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 have been required as of March 31, 2017.

(in millions)
Collateral posted as of March 31, 20171	$	93
Incremental collateral requirements for power contracts resulting from a potential downgrade of SCE's credit rating to below investment grade	22
Incremental collateral requirements for power contracts resulting from adverse market price movement2	3
Posted and potential collateral requirements	$	118

¹  Net collateral is provided to counterparties and other brokers in the form of letters of credit and surety bonds.

²  Incremental collateral requirements were based on potential changes in SCE's forward positions as of March 31, 2017 due to adverse market price movements over the remaining lives of the existing power contracts using a 95% confidence level.

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 bank and capital markets.

At March 31, 2017, Edison International Parent had $955 million available under its $1.25 billion multi-year revolving credit facility. In March 2017, Edison International issued $400 million of senior notes. 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 March 31, 2017, Edison International Parent's consolidated debt to total capitalization ratio was 0.48 to 1.

At March 31, 2017, Edison International Parent was in compliance with all other financial covenants that affect access to capital.

Historical Cash Flows

Southern California Edison Company

	Three months ended March 31,
(in millions)	2017			2016
Net cash provided by operating activities	$	931		$	884
Net cash provided by (used in) financing activities	56			(57		)
Net cash used in investing activities	(926		)	(832		)
Net increase (decrease) in cash and cash equivalents	$	61		$	(5	)

9

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 the three months ended March 31, 2017 and 2016.

	Three months ended March 31,						Change in cash flows
(in millions)	2017			2016			2017/2016
Net income	$	380		$	325
Non-cash items1	724			531
Subtotal	$	1,104		$	856		$	248
Changes in cash flow resulting from working capital2	(155		)	(35		)	(120		)
Derivative assets and liabilities	(12		)	5			(17		)
Regulatory assets and liabilities	129			119			10
Other noncurrent assets and liabilities3	(135		)	(61		)	(74		)
Net cash provided by operating activities	$	931		$	884		$	47

¹  Non-cash items include depreciation, decommissioning and amortization, allowance for equity during construction, 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 increased in 2017 by $55 million primarily due to higher authorized revenue in 2017 due to the escalation mechanism as set forth in the 2015 GRC decision, lower operation and maintenance expenses, and higher income tax benefits, partially offset by higher net financing costs.

Net cash for working capital was $(155) million and $(35) million during the three months ended March 31, 2017 and 2016, respectively. The net cash for each period was primarily related to the reductions of payables (including payments for payroll-related costs and purchase power) of $230 million and $215 million during the first quarters of 2017 and 2016, respectively, partially offset by reductions of receivables from customers ($130 million and $170 million in 2017 and 2016, respectively).

Net cash provided by regulatory assets and liabilities, including changes in over (under) collections of balancing accounts was $129 million and $119 million during the three months ended March 31, 2017 and 2016, 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:

2017

• Higher cash due to $64 million of overcollections for the public purpose and energy efficiency programs. Overcollections for public purpose and energy efficiency programs increased due to lower spending for these programs.

• Higher cash due to realization of $47 million in proceeds from the MHI arbitration. For further information on the MHI claims, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."

• BRRBA overcollections decreased by $66 million during the first three months of 2017 primarily due to the 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. The BRRBA tracks the differences between amounts authorized by the CPUC in the GRC proceedings and amounts billed to customers.

• SCE had an increase in cash of approximately $84 million primarily due to lower spending for the new system generation program, which records the benefits and costs of power purchase agreements and SCE-owned peaker generation units associated with new generation resources.

10

2016

• Higher cash due to an increase in overcollections of $134 million for the public purpose and energy efficiency programs due to lower spending for these programs during the first three months of 2016.

• ERRA overcollections for fuel and purchased power decreased by $75 million during the first three months of 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.

• SCE had an increase in cash of approximately $60 million primarily due to the timing of greenhouse gas auction revenue and climate credit refunds to customers.

Cash flows used in other noncurrent assets and liabilities were primarily related to net earnings from nuclear decommissioning trust investments ($27 million and $10 million in 2017 and 2016, respectively) and SCE's payments of decommissioning costs ($45 million and $41 million in 2017 and 2016, respectively). See "Nuclear Decommissioning Activities" below for further discussion.

Net Cash Provided by (Used in) Financing Activities

The following table summarizes cash provided by (used in) financing activities for the three months ended March 31, 2017 and 2016. Issuances of debt are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Long-Term Debt."

	Three months ended March 31,
(in millions)	2017			2016
Issuances of first and refunding mortgage bonds, net of discount and issuance costs	$	692		$	—
Issuance of term loan	300			—
Remarketing of pollution control bonds, net of issuance costs	134			—
Long-term debt matured or repurchased	(40		)	(40		)
Issuances of preference stock, net of issuance costs	—			294
Redemptions of preference stock	—			(125		)
Short-term debt (repayments), net of borrowings and discount	(769		)	52
Payments of common stock dividends to Edison International	(191		)	(170		)
Payments of preferred and preference stock dividends	(36		)	(35		)
Other	(34		)	(33		)
Net cash provided by (used in) financing activities	$	56		$	(57	)

Net Cash Used in Investing Activities

Cash flows used in investing activities are primarily due to capital expenditures related to transmission and distribution investments ($929 million and $950 million for the three months ended March 31, 2017 and 2016, respectively). In addition, in the first three months of 2016, SCE had a net redemption of nuclear decommissioning trust investments of $106 million. See "Nuclear Decommissioning Activities" below for further discussion.

11

Nuclear Decommissioning Activities

SCE's statement of cash flows includes nuclear decommissioning activities, which are reflected in the following line items:

	Three months ended March 31,
(in millions)	2017			2016
Net cash used in operating activities:    Net earnings from nuclear decommissioning trust investments	$	27		$	10
SCE's decommissioning costs	(45		)	(41		)
Net cash flow from investing activities:    Proceeds from sale of investments	1,718			793
Purchases of investments	(1,719		)	(687		)
Net cash impact	$	(19	)	$	75

Net cash used in operating activities relate to interest and dividends less administrative expenses, taxes, and SCE's decommissioning costs. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information. Investing activities represent the purchase and sale of investments within the nuclear decommissioning trusts, including the reinvestment of earnings from nuclear decommissioning trust investments. The net cash impact reflects timing of decommissioning payments ($45 million and $41 million in 2017 and 2016, respectively) and reimbursements to SCE from the nuclear decommissioning trust ($26 million and $116 million in 2017 and 2016, respectively). The 2016 net cash impact included reimbursements for 2016 and a portion of 2015, 2014, and 2013 decommissioning costs.

Edison International Parent and Other

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

	Three months ended March 31,
(in millions)	2017			2016
Net cash used in operating activities	$	(52	)	$	(29	)
Net cash provided by financing activities	56			12
Net cash used in investing activities	(11		)	(2		)
Net decrease in cash and cash equivalents	$	(7	)	$	(19	)

Net Cash Used in Operating Activities

Net cash used in operating activities increased $23 million during the first three months of 2017 compared to 2016 due to higher interest payments related to long-term debt and the timing of payments and receipts relating to operating costs.

Net Cash Provided by Financing Activities

Net cash provided by financing activities was as follows:

	Three months ended March 31,
(in millions)	2017			2016
Dividends paid to Edison International common shareholders	$	(177	)	$	(156	)
Dividends received from SCE	191			170
Payment for stock-based compensation, net of receipt from stock option exercises	(116		)	(16		)
Long-term debt issuance, net of discount and issuance costs	398			397
Short-term debt repayments, net of borrowings and discount	(244		)	(384		)
Other	4			1
Net cash provided by financing activities	$	56		$	12

12

Contingencies

SCE has contingencies related to San Onofre Related Matters, Nuclear Insurance, Wildfire Insurance, and Spent Nuclear Fuel, which are discussed in "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies."

MARKET RISK EXPOSURES

Edison International's and SCE's primary market risks are described in the 2016 Form 10-K. 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 4. Fair Value Measurements" and "—Note 6. Derivative Instruments."

Commodity Price Risk

The fair value of outstanding derivative instruments used to mitigate exposure to commodity price risk was a net liability of $1.2 billion and $1.1 billion March 31, 2017 and December 31, 2016, respectively. For further discussion of fair value measurements and the fair value hierarchy, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements" and "— Note 6. Derivative Instruments."

Credit Risk

Credit risk exposure from counterparties for power and gas trading activities is measured as the sum of net accounts receivable (accounts receivable less accounts payable) and the current fair value of net derivative assets (derivative assets less derivative liabilities) reflected on the consolidated balance sheets. SCE enters into master agreements which typically provide for a right of 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 March 31, 2017, the amount of balance sheet exposure as described above broken down by the credit ratings of SCE's counterparties, was as follows:

	March 31, 2017
(in millions)	Exposure2		Collateral		Net Exposure
S&P Credit Rating1
A or higher	$	64	$	—	$	64

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

For a complete discussion on Edison International's and SCE's critical accounting policies, see "Critical Accounting Estimates and Policies" in the year-ended 2016 MD&A.

NEW ACCOUNTING GUIDANCE

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

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Information responding to this section is included in the MD&A under the heading "Market Risk Exposures" and is incorporated herein by reference.

13

FINANCIAL STATEMENTS

Consolidated Statements of Income	Edison International
	Three months ended March 31,
(in millions, except per-share amounts, unaudited)	2017			2016
Total operating revenue	$	2,463		$	2,440
Purchased power and fuel	784			794
Operation and maintenance	596			629
Depreciation, decommissioning and amortization	499			477
Property and other taxes	100			92
Impairment and other charges	5			—
Total operating expenses	1,984			1,992
Operating income	479			448
Interest and other income	33			31
Interest expense	(152		)	(140		)
Other expenses	(8		)	(6		)
Income from continuing operations before income taxes	352			333
Income tax (benefit) expense	(40		)	28
Income from continuing operations	392			305
Income from discontinued operations, net of tax	—			1
Net income	392			306
Preferred and preference stock dividend requirements of SCE	31			30
Other noncontrolling interests	(1		)	(5		)
Net income attributable to Edison International common shareholders	$	362		$	281
Amounts attributable to Edison International common shareholders:
Income from continuing operations, net of tax	$	362		$	280
Income from discontinued operations, net of tax	—			1
Net income attributable to Edison International common shareholders	$	362		$	281
Basic earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding	326			326
Continuing operations	$	1.11		$	0.86
Total	$	1.11		$	0.86
Diluted earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding, including effect of dilutive securities	329			329
Continuing operations	$	1.10		$	0.85
Total	$	1.10		$	0.85
Dividends declared per common share	$	0.5425		$	0.4800

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

14

Consolidated Statements of Comprehensive Income	Edison International
	Three months ended March 31,
(in millions, unaudited)	2017		2016
Net income	$	392	$	306
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Amortization of net loss included in net income	2		2
Other	2		—
Other comprehensive income, net of tax	4		2
Comprehensive income	396		308
Less: Comprehensive income attributable to noncontrolling interests	30		25
Comprehensive income attributable to Edison International	$	366	$	283

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

15

Consolidated Balance Sheets	Edison International
(in millions, unaudited)	March 31, 2017		December 31, 2016
ASSETS
Cash and cash equivalents	$	150	$	96
Receivables, less allowances of $55 and $62 for uncollectible accounts at respective dates	688		714
Accrued unbilled revenue	266		370
Inventory	237		239
Derivative assets	69		73
Regulatory assets	394		350
Other current assets	242		281
Total current assets	2,046		2,123
Nuclear decommissioning trusts	4,352		4,242
Other investments	89		83
Total investments	4,441		4,325
Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates	36,951		36,806
Nonutility property, plant and equipment, less accumulated depreciation of $102 and $99 at respective dates	217		194
Total property, plant and equipment	37,168		37,000
Regulatory assets	7,674		7,455
Other long-term assets	411		416
Total long-term assets	8,085		7,871
Total assets	$	51,740	$	51,319

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

16

Consolidated Balance Sheets	Edison International
(in millions, except share amounts, unaudited)	March 31, 2017			December 31, 2016
LIABILITIES AND EQUITY
Short-term debt	$	295		$	1,307
Current portion of long-term debt	981			981
Accounts payable	844			1,342
Accrued taxes	86			50
Customer deposits	272			269
Derivative liabilities	237			216
Regulatory liabilities	804			756
Other current liabilities	897			991
Total current liabilities	4,416			5,912
Long-term debt	11,662			10,175
Deferred income taxes and credits	8,523			8,327
Derivative liabilities	989			941
Pensions and benefits	1,358			1,354
Asset retirement obligations	2,585			2,590
Regulatory liabilities	5,910			5,726
Other deferred credits and other long-term liabilities	2,048			2,102
Total deferred credits and other liabilities	21,413			21,040
Total liabilities	37,491			37,127
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest	7			5
Common stock, no par value (800,000,000 shares authorized; 325,811,206 shares issued and outstanding at respective dates)	2,510			2,505
Accumulated other comprehensive loss	(49		)	(53		)
Retained earnings	9,590			9,544
Total Edison International's common shareholders' equity	12,051			11,996
Noncontrolling interests – preferred and preference stock of SCE	2,191			2,191
Total equity	14,242			14,187
Total liabilities and equity	$	51,740		$	51,319

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

17

Consolidated Statements of Cash Flows	Edison International
	Three months ended March 31,
(in millions, unaudited)	2017			2016
Cash flows from operating activities:
Net income	$	392		$	306
Less: income from discontinued operations	—			1
Income from continuing operations	392			305
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	520			499
Allowance for equity during construction	(19		)	(22		)
Impairment and other charges	5			—
Deferred income taxes and investment tax credits	(13		)	27
Other	5			5
Nuclear decommissioning trusts	1			(106		)
Changes in operating assets and liabilities:
Receivables	26			117
Inventory	2			(1		)
Accounts payable	(226		)	(184		)
Prepaid and accrued taxes	34			66
Other current assets and liabilities	50			(43		)
Derivative assets and liabilities	(12		)	5
Regulatory assets and liabilities	129			119
Other noncurrent assets and liabilities	(15		)	68
Net cash provided by operating activities	879			855
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs of $11 and $3 for respective periods	1,524			397
Long-term debt matured	(40		)	(40		)
Preference stock issued, net	—			294
Preference stock redeemed	—			(125		)
Short-term debt financing, net	(1,013		)	(332		)
Settlements of stock-based compensation, net	(139		)	(51		)
Dividends to noncontrolling interests	(37		)	(35		)
Dividends paid	(177		)	(156		)
Other	(6		)	3
Net cash provided by (used in) financing activities	112			(45		)
Cash flows from investing activities:
Capital expenditures	(939		)	(951		)
Proceeds from sale of nuclear decommissioning trust investments	1,718			793
Purchases of nuclear decommissioning trust investments	(1,719		)	(687		)
Other	3			11
Net cash used in investing activities	(937		)	(834		)
Net increase (decrease) in cash and cash equivalents	54			(24		)
Cash and cash equivalents at beginning of period	96			161
Cash and cash equivalents at end of period	$	150		$	137

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

18

Consolidated Statements of Income	Southern California Edison Company
		Three months ended March 31,
(in millions, unaudited)		2017			2016
Operating revenue		$	2,456		$	2,435
Purchased power and fuel		784			794
Operation and maintenance		571			603
Depreciation, decommissioning and amortization		497			475
Property and other taxes		97			91
Total operating expenses		1,949			1,963
Operating income		507			472
Interest and other income		33			31
Interest expense		(141		)	(131		)
Other expenses		(7		)	(5		)
Income before income taxes		392			367
Income tax expense		12			42
Net income		380			325
Less: Preferred and preference stock dividend requirements		31			30
Net income available for common stock		$	349		$	295

Consolidated Statements of Comprehensive Income
	Three months ended March 31,
(in millions, unaudited)	2017		2016
Net income	$	380	$	325
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Amortization of net loss included in net income	1		1
Other	1		—
Other comprehensive income, net of tax	2		1
Comprehensive income	$	382	$	326

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

19

Consolidated Balance Sheets Southern California Edison Company

(in millions, unaudited)	March 31, 2017		December 31, 2016
ASSETS
Cash and cash equivalents	$	100	$	39
Receivables, less allowances of $55 and $61 for uncollectible accounts at respective dates	670		699
Accrued unbilled revenue	265		369
Inventory	235		239
Derivative assets	69		73
Regulatory assets	394		350
Other current assets	307		262
Total current assets	2,040		2,031
Nuclear decommissioning trusts	4,352		4,242
Other investments	61		50
Total investments	4,413		4,292
Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates	36,951		36,806
Nonutility property, plant and equipment, less accumulated depreciation of $91 and $89 at respective dates	75		75
Total property, plant and equipment	37,026		36,881
Regulatory assets	7,674		7,455
Other long-term assets	231		232
Total long-term assets	7,905		7,687
Total assets	$	51,384	$	50,891

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

20

Consolidated Balance Sheets Southern California Edison Company

(in millions, except share amounts, unaudited)	March 31, 2017			December 31, 2016
LIABILITIES AND EQUITY
Short-term debt	$	—		$	769
Current portion of long-term debt	579			579
Accounts payable	847			1,344
Accrued taxes	88			45
Customer deposits	272			269
Derivative liabilities	237			216
Regulatory liabilities	804			756
Other current liabilities	656			729
Total current liabilities	3,483			4,707
Long-term debt	10,843			9,754
Deferred income taxes and credits	10,323			9,886
Derivative liabilities	989			941
Pensions and benefits	898			896
Asset retirement obligations	2,580			2,586
Regulatory liabilities	5,910			5,726
Other deferred credits and other long-term liabilities	1,735			1,912
Total deferred credits and other liabilities	22,435			21,947
Total liabilities	36,761			36,408
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	660			657
Accumulated other comprehensive loss	(18		)	(20		)
Retained earnings	9,568			9,433
Total common shareholder's equity	12,378			12,238
Preferred and preference stock	2,245			2,245
Total equity	14,623			14,483
Total liabilities and equity	$	51,384		$	50,891

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

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Consolidated Statements of Cash Flows Southern California Edison Company

	Three months ended March 31,
(in millions, unaudited)	2017			2016
Cash flows from operating activities:
Net income	$	380		$	325
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	517			496
Allowance for equity during construction	(19		)	(22		)
Deferred income taxes and investment tax credits	223			54
Other	3			3
Nuclear decommissioning trusts	1			(106		)
Changes in operating assets and liabilities:
Receivables	28			100
Inventory	5			5
Accounts payable	(226		)	(175		)
Prepaid and accrued taxes	(33		)	60
Other current assets and liabilities	71			(25		)
Derivative assets and liabilities	(12		)	5
Regulatory assets and liabilities	129			119
Other noncurrent assets and liabilities	(136		)	45
Net cash provided by operating activities	931			884
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs of $9 for the three months ended March 31, 2017	1,126			—
Long-term debt matured	(40		)	(40		)
Preference stock issued, net	—			294
Preference stock redeemed	—			(125		)
Short-term debt financing, net	(769		)	52
Dividends paid	(227		)	(205		)
Other	(34		)	(33		)
Net cash provided by (used in) financing activities	56			(57		)
Cash flows from investing activities:
Capital expenditures	(929		)	(950		)
Proceeds from sale of nuclear decommissioning trust investments	1,718			793
Purchases of nuclear decommissioning trust investments	(1,719		)	(687		)
Other	4			12
Net cash used in investing activities	(926		)	(832		)
Net increase (decrease) in cash and cash equivalents	61			(5		)
Cash and cash equivalents, beginning of period	39			26
Cash and cash equivalents, end of period	$	100		$	21

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

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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, Inc., 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 competitive 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 significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 2016 (the "2016 Form 10-K"). This quarterly report should be read in conjunction with the financial statements and notes included in the 2016 Form 10-K.

In the opinion of management, all adjustments, consisting of recurring accruals, have been made that are necessary to fairly state the consolidated financial position, results of operations, and cash flows in accordance with accounting principles generally accepted in the United States ("GAAP") for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three-month period ended March 31, 2017 are not necessarily indicative of the operating results for the full year.

The December 31, 2016 financial statement data was derived from audited financial statements, but does not include all disclosures required by GAAP.

During the fourth quarter of 2016, Edison International and SCE early adopted an accounting standard for share-based payments using the modified retrospective approach, effective January 1, 2016. Prior year financial statements have been updated to reflect the modified retrospective application of this accounting standard. For further information, see Note 1 and Note 18 of "Notes to Consolidated Financial Statements" included in the 2016 Form 10-K and Note 2 and Note 7 of this Form 10-Q.

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
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Money market funds	$	111	$	41	$	87	$	18

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
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Book balances reclassified to accounts payable	$	75	$	138	$	70	$	136

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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:

	Three months ended March 31,
(in millions, except per-share amounts)	2017		2016
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Weighted average common shares outstanding	326		326
Basic earnings per share – continuing operations	$	1.11	$	0.86
Diluted earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Income impact of assumed conversions	—		—
Income from continuing operations available to common shareholders and assumed conversions	$	362	$	280
Weighted average common shares outstanding	326		326
Incremental shares from assumed conversions	3		3
Adjusted weighted average shares – diluted	329		329
Diluted earnings per share – continuing operations	$	1.10	$	0.85

In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 1,355,930 and 2,023,787 shares of common stock for the three months ended March 31, 2017 and 2016, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.

New Accounting Guidance

Accounting Guidance Not Yet Adopted

In May 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016 and 2017. 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. As of March 31, 2017, approximately 98% of total operating revenue arises from SCE's tariff offerings that provide electricity to customers. For such arrangements, revenue from contracts with customers will be equivalent to the electricity supplied and billed in that period (including estimated billings). As such, there will not be a change in the timing or pattern of revenue recognition for such sales. 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

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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.

The FASB also issued accounting standards updates related to the impairment of financial instruments (effective January 1, 2020) and the presentation of certain cash receipts and payments in the statement of cash flows (effective January 1, 2018). Edison International and SCE are currently evaluating these updates to accounting standards.

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.

In March 2017, the FASB issued an accounting standards update which amends the current requirements related to the presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's results of operations, but will result in the separate presentation of service costs as an operating expense and non-service costs within other income and expense. Edison International and SCE are currently evaluating the impact this standard will have on the consolidated balance sheets. The new standards update is effective on January 1, 2018. It is required to be applied on a retrospective basis for the presentation of the service cost component and the other components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit cost.

Note 2.    Consolidated Statements of Changes in Equity

The following table provides Edison International's changes in equity for the three months ended March 31, 2017:

	Equity Attributable to Common Shareholders											Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings			Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2016	$	2,505	$	(53	)	$	9,544		$	11,996		$	2,191		$	14,187
Net income	—		—			362			362			31			393
Other comprehensive income	—		4			—			4			—			4
Common stock dividends declared ($0.5425 per share)	—		—			(177		)	(177		)	—			(177		)
Dividends to noncontrolling interests	—		—			—			—			(31		)	(31		)
Stock-based compensation	—		—			(139		)	(139		)	—			(139		)
Non-cash stock-based compensation	5		—			—			5			—			5
Balance at March 31, 2017	$	2,510	$	(49	)	$	9,590		$	12,051		$	2,191		$	14,242

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The following table provides Edison International's changes in equity for the three months ended March 31, 2016:

	Equity Attributable to Common Shareholders												Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings				Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2015	$	2,484	$	(56	)	$	8,940			$	11,368		$	2,020		$	13,388
Net income	—		—			281			1	281			30			311
Other comprehensive income	—		2			—				2			—			2
Common stock dividends declared ($0.4800 per share)	—		—			(156		)		(156		)	—			(156		)
Dividends to noncontrolling interests	—		—			—				—			(30		)	(30		)
Stock-based compensation	—		—			(8		)	1	(8		)	—			(8		)
Non-cash stock-based compensation	6		—			—				6			—			6
Issuance of preference stock	—		—			—				—			294			294
Redemption of preference stock	—		—			(3		)		(3		)	(122		)	(125		)
Balance at March 31, 2016	$	2,490	$	(54	)	$	9,054			$	11,490		$	2,192		$	13,682

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 and stock-based compensation (as previously reported) were $271 million and $(50) million, respectively, for the three months ended March 31, 2016.

The following table provides SCE's changes in equity for the three months ended March 31, 2017:

	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, 2016	$	2,168	$	657	$	(20	)	$	9,433		$	2,245	$	14,483
Net income	—		—		—			380			—		380
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(191		)	—		(191		)
Dividends declared on preferred and preference stock	—		—		—			(31		)	—		(31		)
Stock-based compensation	—		—		—			(23		)	—		(23		)
Non-cash stock-based compensation	—		3		—			—			—		3
Balance at March 31, 2017	$	2,168	$	660	$	(18	)	$	9,568		$	2,245	$	14,623

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The following table provides SCE's changes in equity for the three months ended March 31, 2016:

	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, 2015	$	2,168	$	652		$	(22	)	$	8,804			$	2,070		$	13,672
Net income	—		—			—			325			1	—			325
Other comprehensive income	—		—			1			—				—			1
Dividends declared on common stock	—		—			—			(170		)		—			(170		)
Dividends declared on preferred and preference stock	—		—			—			(30		)		—			(30		)
Stock-based compensation	—		—			—			(28		)	1	—			(28		)
Non-cash stock-based compensation	—		3			—			—				—			3
Issuance of preference stock	—		(6		)	—			—				300			294
Redemption of preference stock	—		3			—			(3		)		(125		)	(125		)
Balance at March 31, 2016	$	2,168	$	652		$	(21	)	$	8,898			$	2,245		$	13,942

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 and stock-based compensation (as previously reported) were $317 million and $(34) million, respectively, for the three months ended March 31, 2016.

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. Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs. Commercial and operating activities include construction, operation and maintenance, fuel procurement, dispatch, and compliance with regulatory and contractual requirements.

Variable Interest in VIEs that are not Consolidated

Power Purchase Agreements

SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities 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 California Public Utilities Commission ("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 of the 2016 Form 10-K. 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 4,928 MW and 4,383 MW at March 31, 2017 and 2016, respectively, and the amounts that SCE paid to these projects were $140 million and $127 million for the three months ended March 31, 2017 and 2016, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.

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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. 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.

The Trust I, Trust II, Trust III, Trust IV, and Trust V balance sheets as of March 31, 2017 and December 31, 2016, consisted of investments of $475 million, $400 million, $275 million, $325 million, and $300 million in the Series F, Series G, Series H, Series J, and Series K Preference Stock, respectively, $475 million, $400 million, $275 million, $325 million, and $300 million of trust securities, respectively, and $10,000 each of common stock.

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

	Three months ended March 31,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2017
Dividend income	$	7	$	5	$	4	$	4	$	4
Dividend distributions	7		5		4		4		4
2016
Dividend income	$	7	$	5	$	4	$	4	$	1
Dividend distributions	7		5		4		4		1

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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 March 31, 2017 and December 31, 2016, 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.

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 derivative instruments.

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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:

	March 31, 2017
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	15	$	55		$	—	$	70
Other	103		—		—			—		103
Nuclear decommissioning trusts:
Stocks2	1,537		—		—			—		1,537
Fixed Income3	1,153		1,588		—			—		2,741
Short-term investments, primarily cash equivalents	88		84		—			—		172
Subtotal of nuclear decommissioning trusts4	2,778		1,672		—			—		4,450
Total assets	2,881		1,687		55			—		4,623
Liabilities at fair value
Derivative contracts	—		5		1,221			—		1,226
Total liabilities	—		5		1,221			—		1,226
Net assets (liabilities)	$	2,881	$	1,682	$	(1,166	)	$	—	$	3,397

	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

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 68% and 70% of SCE's equity investments were located in the United States at March 31, 2017 and December 31, 2016, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $83 million and $79 million at March 31, 2017 and December 31, 2016, respectively.

⁴  Excludes net payables of $98 million and $127 million at March 31, 2017 and December 31, 2016, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

Edison International Parent and Other

Edison International Parent and Other assets measured at fair value consisted of money market funds of $24 million and $23 million at March 31, 2017 and December 31, 2016, respectively, classified as Level 1.

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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:

	Three months ended March 31,
(in millions)	2017			2016
Fair value of net liabilities at beginning of period	$	(1,089	)	$	(1,148	)
Total realized/unrealized losses:
Included in regulatory assets and liabilities1	(77		)	(65		)
Fair value of net liabilities at end of period	$	(1,166	)	$	(1,213	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	(102	)	$	(84	)

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 material transfers between any levels during 2017 and 2016.

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.

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
March 31, 2017	$	55	$	—	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, 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
Tolling
March 31, 2017	—		1,210		Option model	Volatility of gas prices	16% - 39% (25%)
						Volatility of power prices	26% - 140% (36%)
						Power prices	$18.01 - $45.28 ($30.70)
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)

¹  Prices are in dollars per megawatt-hour.

²  Prices are in dollars per million British thermal units.

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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.

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:

	March 31, 2017				December 31, 2016
(in millions)	Carrying Value1		Fair Value		Carrying Value1		Fair Value
SCE	$	11,422	$	12,665	$	10,333	$	11,539
Edison International	12,643		13,894		11,156		12,368

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

In January 2017, SCE borrowed $300 million under a Term Loan Agreement due July 2018, with a variable interest rate based on the London Interbank Offered Rate plus 65 basis points (1.53% at March 31, 2017). The proceeds were used for general corporate purposes.

In January 2017, SCE reissued $135 million of 2.625% pollution-control bonds subject to mandatory remarketing in December 2023. The proceeds were used for general corporate purposes.

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In March 2017, SCE issued $700 million of 4.00% first and refunding mortgage bonds due in 2047 and Edison International issued $400 million of 2.125% senior notes due in 2020. The proceeds were used to repay commercial paper borrowings and for general corporate purposes. In addition, the proceeds from SCE's bonds were used to fund SCE's capital program.

Credit Agreements and Short-Term Debt

SCE and Edison International Parent have multi-year revolving credit facilities of $2.75 billion and $1.25 billion, respectively, 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 March 31, 2017, SCE had no outstanding commercial paper. At March 31, 2017, 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, 2016, the outstanding commercial paper, net of discount, was $769 million at a weighted-average interest rate of 0.9%.

At March 31, 2017, Edison International Parent's outstanding commercial paper, net of discount, was $295 million at a weighted-average interest rate of 1.18%. At December 31, 2016, the outstanding commercial paper, net of discount, was $538 million at a weighted-average interest rate of 0.97%.

Note 6.    Derivative Instruments

Derivative financial instruments are used to manage exposure to commodity price risk. These risks are managed in part by entering into forward commodity transactions, including options, swaps, and futures. To mitigate credit risk from counterparties in the event of nonperformance, master netting agreements are used whenever possible and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.

Commodity Price Risk

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

Credit and Default Risk

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

Certain power 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 $19 million and $12 million as of March 31, 2017 and December 31, 2016, respectively, for which SCE has posted $12 million collateral at both March 31, 2017 and December 31, 2016 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 March 31, 2017, SCE would be required to post $8 million of additional collateral of which $2 million is related to outstanding payables that are net of collateral already posted.

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Fair Value of Derivative Instruments

SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are 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:

	March 31, 2017
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	70		$	1	$	71		$	238		$	989	$	1,227		$	1,156
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	69		$	1	$	70		$	237		$	989	$	1,226		$	1,156

	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 the 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

¹  In addition, at March 31, 2017, there is no cash collateral posted that is not offset against derivative liabilities. 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.

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 purchased power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are 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:

	Three months ended March 31,
(in millions)	2017			2016
Realized losses	$	(2	)	$	(27	)
Unrealized losses	(85		)	(64		)

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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
Commodity	Unit of Measure	March 31, 2017	December 31, 2016
Electricity options, swaps and forwards	GWh	1,812	1,816
Natural gas options, swaps and forwards	Bcf	123	36
Congestion revenue rights	GWh	79,224	93,319
Tolling arrangements	GWh	58,153	61,093

Note 7.    Income Taxes

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
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Income from continuing operations before income taxes	$	352		$	333		$	392		$	367
Provision for income tax at federal statutory rate of 35%	124			117			137			128
Increase in income tax from:
State tax, net of federal benefit	10			6			13			9
Property-related	(113		)	(79		)	(113		)	(79		)
Change related to uncertain tax positions	(12		)	(1		)	(11		)	(1		)
Shared-based compensation1	(43		)	(10		)	(8		)	(8		)
Other	(6		)	(5		)	(6		)	(7		)
Total income tax (benefit) expense from continuing operations	$	(40	)	$	28		$	12		$	42
Effective tax rate	(11.4		)%	8.4		%	3.1		%	11.4		%

¹   Includes state taxes for Edison International and SCE of $6 million and $1 million, respectively, for the three months ended March 31, 2017 and $3 million and $2 million, respectively, for the three months ended March 31, 2016. 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.

In March 2017, SCE received the final decision on claims against, and counterclaims of, Mitsubishi Heavy Industries, Inc. and related companies (together, "MHI") from the arbitration tribunal, the International Chamber of Commerce, discussed further in Note 11. San Onofre was permanently shut down on June 7, 2013 as a result of failure of replacement steam generators supplied by MHI. With the resolution of the insurance claim against Nuclear Electric Insurance Limited ("NEIL") in October 2015 and the conclusion of the arbitration proceeding against MHI, a tax abandonment loss of $698 million and $1.14 billion for federal and state income tax purposes, respectively, was claimed in the first quarter of 2017, resulting in a flow-through tax benefit of approximately $39 million impacting the effective tax rate. Due to the tax abandonment loss recognized this quarter, Edison International and SCE both expect to report a federal taxable loss in 2017. In addition, Edison International expects to report a California taxable loss in 2017. 

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Unrecognized Tax Benefits

In the first quarter of 2017, Edison International settled all open tax positions with the Internal Revenue Service ("IRS") for taxable years 2007 through 2012. The following table provides a reconciliation of unrecognized tax benefits for 2017 as a result of the audit settlement:

(in millions)	Edison International			SCE
Balance at January 1, 2017	$	471		$	371
Tax positions taken during the current year:
Increases	10			10
Tax positions taken during a prior year:
Increases	2			2
Decreases	(10		)	(10		)
Decreases for settlements during the period	(82		)	(78		)
Balance at March 31, 2017	$	391		$	295

Tax Disputes

Tax Years 2007 – 2012

In the first quarter of 2017, Edison International settled all open tax positions with the IRS for taxable years 2007 through 2012. Edison International previously made cash deposits which are sufficient to settle all outstanding liabilities for this audit cycle. Total liabilities included tax reserves, previously settled issues, and an estimate of associated interest and penalties. 

Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2013 – 2015 and 2010 – 2015, respectively. Edison International has settled all open tax position with the IRS for taxable years prior to 2013.  Tax years 2003 – 2009 are currently under protest with the California Franchise Tax Board.

Note 8.    Compensation and Benefit Plans

Pension Plans

Edison International made contributions of $25 million during the three months ended March 31, 2017, which includes contributions of $21 million by SCE. Edison International expects to make contributions of $111 million during the remainder of 2017, which includes $64 million from SCE. Annual contributions made by SCE to most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms.

Pension expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	36		$	39		$	35		$	38
Interest cost	41			44			37			41
Expected return on plan assets	(53		)	(56		)	(50		)	(53		)
Amortization of prior service cost	1			1			1			1
Amortization of net loss1	5			9			4			8
Expense under accounting standards	$	30		$	37		$	27		$	35
Regulatory adjustment	(3		)	(9		)	(3		)	(9		)
Total expense recognized	$	27		$	28		$	24		$	26

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $2 million, respectively, for the three months ended March 31, 2017, and $3 million and $2 million, respectively, for the three months ended March 31, 2016.

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Under GAAP, a settlement is recorded when lump-sum payments exceed estimated annual service and interest costs. Lump sum payments made in April 2017 to Edison International executives retiring in 2016 from the Executive Retirement Plan exceeded the estimated service and interest costs, resulting in a partial settlement of that plan. A settlement loss of approximately $7.7 million ($4.6 million after-tax) is expected to be recorded at Edison International in the second quarter of 2017.

Postretirement Benefits Other Than Pensions

Edison International made contributions of $5 million during the three months ended March 31, 2017 and expects to make contributions of $16 million during the remainder of 2017, substantially all of which are expected to be made by SCE. 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. Benefits under these plans, with some exceptions, are generally unvested and subject to change. Under the terms of the Edison International Health and Welfare Plan ("PBOP Plan") each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of all PBOP Plan benefits with respect to its employees and former employees. A participating employer may terminate the PBOP Plan benefits with respect to its employees and former employees, as may SCE (as PBOP Plan sponsor), and, accordingly, the participants' PBOP Plan benefits are not vested benefits.

PBOP expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	9		$	10		$	9		$	10
Interest cost	24			26			24			26
Expected return on plan assets	(27		)	(28		)	(27		)	(28		)
Amortization of prior service cost	(1		)	(1		)	(1		)	(1		)
Total expense	$	5		$	7		$	5		$	7

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 Dates	Amortized Cost				Fair Value
(in millions)		March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Stocks	—	$	291	$	319	$	1,537	$	1,547
Municipal bonds	2054	645		659		753		766
U.S. government and agency securities	2055	1,308		1,131		1,380		1,191
Corporate bonds	2057	552		600		608		659
Short-term investments and receivables/payables1	One-year	71		75		74		79
Total		$	2,867	$	2,784	$	4,352	$	4,242

¹ Short-term investments include $36 million and $114 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by April 3, 2017 and January 4, 2017 as of March 31, 2017 and December 31, 2016, respectively.

Trust fund earnings (based on specific identification) increase the trust fund balance and the asset retirement obligation ("ARO") regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion at both March 31, 2017 and December 31, 2016.

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The following table sets forth a summary of changes in the fair value of the trust:

	Three months ended March 31,
(in millions)	2017			2016
Balance at beginning of period	$	4,242		$	4,331
Gross realized gains	99			17
Gross realized losses	(16		)	(3		)
Unrealized gains, net of losses	27			59
Other-than-temporary impairments	(1		)	(7		)
Interest and dividends	28			29
Income taxes	—			(18		)
Decommissioning disbursements	(26		)	(116		)
Administrative expenses and other	(1		)	(2		)
Balance at end of period	$	4,352		$	4,290

Trust assets are used to pay income taxes. Deferred tax liabilities related to net unrealized gains at March 31, 2017 were $373 million. Accordingly, the fair value of trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $4.0 billion at March 31, 2017. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.

Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts.

Note 10.    Regulatory Assets and Liabilities

Regulatory Assets

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	139	$	135
Energy derivatives	186		150
Unamortized investments, net of accumulated amortization	37		49
Other	32		16
Total current	394		350
Long-term:
Deferred income taxes, net of liabilities	4,689		4,478
Pensions and other postretirement benefits	711		710
Energy derivatives	996		947
Unamortized investments, net of accumulated amortization	79		80
San Onofre	815		857
Unamortized loss on reacquired debt	180		184
Regulatory balancing accounts	68		66
Environmental remediation	125		126
Other	11		7
Total long-term	7,674		7,455
Total regulatory assets	$	8,068	$	7,805

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Regulatory Liabilities

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	740	$	736
San Onofre MHI arbitration award1	47		—
Other	17		20
Total current	804		756
Long-term:
Costs of removal	2,838		2,847
Recoveries in excess of ARO liabilities2	1,735		1,639
Regulatory balancing accounts	1,278		1,180
Other	59		60
Total long-term	5,910		5,726
Total regulatory liabilities	$	6,714	$	6,482

¹ Represents SCE's net recovery from claims against MHI. See Note 11 for further discussion.

² Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9 for further discussion.

Net Regulatory Balancing Accounts

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

(in millions)	March 31, 2017			December 31, 2016
Asset (liability)
Energy resource recovery account	$	30		$	(20	)
New system generation balancing account	(97		)	(6		)
Public purpose programs and energy efficiency programs	(1,056		)	(992		)
Tax accounting memorandum account and pole loading balancing account	(136		)	(142		)
Base rate recovery balancing account	(360		)	(426		)
Department of Energy litigation memorandum account	(123		)	(122		)
Greenhouse gas auction revenue	(3		)	31
FERC balancing accounts	(93		)	(69		)
Other	27			31
Liability	$	(1,811	)	$	(1,715	)

Note 11.    Commitments and Contingencies

Third-Party Power Purchase Agreements

During the first quarter of 2017, SCE had existing PPAs that met the critical contract provisions. The commitments for these contracts are estimated to be: $48 million in 2017, $116 million in 2018, $117 million in 2019, $119 million in 2020, $120 million in 2021, and $955 million for the remaining period thereafter. For further information, see Note 11 in the 2016 Form 10-K.

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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 the Mountainview power plant'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 Settlement Agreement by and among SCE, The Utility Reform Network, the CPUC's Office of Ratepayer Advocates and San Diego Gas & Electric ("SDG&E"), which was later joined by the Coalition of California Utility Employees and Friends of the Earth, dated November 20, 2014 (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 Order Instituting Investigation ("OII") proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned administrative law judge ("ALJ") to consider whether, in light of SCE 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 San Onofre OII Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the San Onofre 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 San Onofre 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 and SDG&E to meet and confer with the other parties in the San Onofre 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. The parties held three meet-and-confer sessions. In March 2017, SCE and other parties reported to the CPUC that the parties participating in the meet-and-confer process have agreed to mediate the issues identified in the December 2016 joint ruling. In April 2017, SCE and other meet-and-confer parties filed a joint motion to extend the April 28, 2017 joint report deadline to August 15, 2017. SCE has recorded a regulatory asset of $815 million at March 31, 2017 to reflect the expected recoveries under the San Onofre OII Settlement Agreement. Management assesses at the end of each reporting period whether regulatory assets are probable of future recovery. SCE assessed the San Onofre regulatory asset at March 31, 2017 and continues to conclude that the asset is

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probable, though not certain, of recovery based on SCE's knowledge of facts and judgment in applying the relevant regulatory principles to the issue. SCE does not believe that the conclusions in the MHI arbitration, discussed below, change the expectation on the probability of recovery of the San Onofre regulatory asset.

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. In light of the San Onofre OII meet-and-confer sessions, the Ninth Circuit cancelled the hearing 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 federal 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 and a decision is pending.

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 federal court granted defendants' motion to dismiss the consolidated complaint, with an opportunity for plaintiffs to amend the complaint. Plaintiffs did not file an amended complaint by the required date. Plaintiffs' deadline to appeal the federal court's order granting defendants' motion to dismiss lapsed in March 2017 and no appeal was filed.

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. 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. These defendants' motion was heard by the court in November 2016 and a decision is pending.

Edison International and SCE cannot predict the outcome of the open proceedings.

MHI Claims

SCE pursued claims against MHI, which designed and supplied the replacement steam generators. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce seeking damages for all losses. SCE alleged contract and tort claims and sought at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI denied any liability and asserted counterclaims for $41 million, for which SCE denied any liability. Each of the other San Onofre owners (SDG&E and Riverside) 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 were added as additional claimants in the arbitration. In March 2017, the arbitration

41

tribunal found MHI liable for breach of contract, but rejected claimants' other claims. The tribunal found that damages were subject to contractual limitations on liability. In addition, the tribunal ordered the claimants to pay MHI's legal costs but rejected MHI's counterclaims. The net recovery awarded to SCE was initially determined to be $52 million. An adjustment to the interest awarded to SCE subsequently reduced the net recovery to approximately $47 million. The decision is the final award of the tribunal but can be challenged in court on limited grounds. SCE has determined that it will not appeal the decision. As a result of uncertainty associated with the allocation of the award under the San Onofre OII Settlement Agreement, SCE recorded a regulatory liability for the net recovery.

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 March 31, 2017, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites with a liability balance at March 31, 2017, in which the upper end of the range of the costs is at least $1 million) was $127 million, including $75 million related to San Onofre. In addition to these sites, SCE also has 17 immaterial sites with a liability balance as of March 31, 2017, for which the total minimum recorded liability was $3 million. Of the $130 million total environmental remediation liability for SCE, $125 million has been recorded as a regulatory asset. SCE expects to recover $47 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $78 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.

The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $149 million and $8 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.

SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next five years are expected to range from $5 million to $18 million. Costs incurred for the three months ended March 31, 2017 and 2016 were $2 million and $1 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

SCE is a member of NEIL, a mutual insurance company owned by entities with nuclear facilities. NEIL provides insurance for nuclear property damage, including damages caused by acts of terrorism up to specified limits, and for accidental outages for active facilities. The amount of nuclear property damage insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $1.06 billion. If NEIL losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $52 million per year.

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. Based on its ownership interests, SCE could

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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.

For more information on nuclear insurance coverage, see Note 11 in the 2016 Form 10-K.

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 U.S. Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. 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 accepted the DOE's determination, and the government will pay the 2014 – 2015 claim under the terms of the settlement. 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.    Accumulated Other Comprehensive Loss

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

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Beginning balance	$	(53	)	$	(56	)	$	(20	)	$	(22	)
Pension and PBOP – net loss:
Reclassified from accumulated other comprehensive loss1	2			2			1			1
Other	2			—			1			—
Change	4			2			2			1
Ending Balance	$	(49	)	$	(54	)	$	(18	)	$	(21	)

¹  These items are included in the computation of net periodic pension and PBOP Plan expense. See Note 8 for additional information.

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Note 13.    Interest and Other Income and Other Expenses

Interest and other income and other expenses are as follows:

	Three months ended March 31,
(in millions)	2017			2016
SCE interest and other income:
Equity allowance for funds used during construction	$	19		$	22
Increase in cash surrender value of life insurance policies and life insurance benefits	12			7
Interest income	1			—
Other	1			2
Total SCE interest and other income	33			31
Total Edison International interest and other income	$	33		$	31
SCE other expenses:
Civic, political and related activities and donations	$	(4	)	$	(5	)
Other	(3		)	—
Total SCE other expenses	(7		)	(5		)
Other expenses of Edison International Parent and Other	(1		)	(1		)
Total Edison International other expenses	$	(8	)	$	(6	)

Note 14.    Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International				SCE
	Three months ended March 31,
(in millions)	2017		2016		2017		2016
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	167	$	158	$	152	$	149
Tax payments, net of refunds	—		2		—		11
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	177	$	156	$	—	$	—
Preferred and preference stock	1		1		1		1

SCE's accrued capital expenditures at March 31, 2017 and 2016 were $275 million and $360 million, respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid.

CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

The management of Edison International and SCE, under the supervision and with the participation of Edison International's and SCE's respective Chief Executive Officers and Chief Financial Officers, have evaluated the effectiveness of Edison International's and SCE's disclosure controls and procedures (as that term is defined in Rules 13a-15(e) or 15d-15(e) under the Securities Exchange Act of 1934, as amended), respectively, as of the end of the first quarter of 2017. Based on that evaluation, Edison International's and SCE's respective Chief Executive Officers and Chief Financial Officers have each concluded that, as of the end of the period, Edison International's and SCE's disclosure controls and procedures, respectively, were effective.

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Changes in Internal Control Over Financial Reporting

There were no changes in Edison International's or SCE's internal control over financial reporting, respectively, during the first quarter of 2017 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 as discussed in Note 2. Property, Plant and Equipment in the 2016 Form 10-K.

LEGAL PROCEEDINGS

None.

UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

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 first quarter of 2017.

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
January 1, 2017 to January 31, 2017	1,071,723		$	72.35	—	—
February 1, 2017 to February 28, 2017	2,778,550		74.02		—	—
March 1, 2017 to March 31, 2017	447,903		79.65		—	—
Total	4,298,176		$	74.19	—	—

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.

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EXHIBITS

Exhibit Number	Description
10.1**	Edison International 2017 Executive Annual Incentive Program
10.2**	Edison International 2017 Long-Term Incentives Terms and Conditions
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 quarterly report on Form 10-Q of Edison International for the quarter ended March 31, 2017, filed on May 1, 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; and (v) the Notes to Consolidated Financial Statements
101.2	Financial statements from the quarterly report on Form 10-Q of Southern California Edison Company for the quarter ended March 31, 2017, filed on May 1, 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; and (v) the Notes to Consolidated Financial Statements

________________________________________

** Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3) of Form 10-K.

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SIGNATURES

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

	EDISON INTERNATIONAL		SOUTHERN CALIFORNIA EDISON COMPANY
By:	/s/ Aaron D. Moss	By:	/s/ 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:	May 1, 2017	Date:	May 1, 2017

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EX-10.1

Exhibit 10.1

EDISON INTERNATIONAL

2017 Executive Annual Incentive Program

1. PURPOSE

The purpose of this Edison International 2017 Executive Annual Incentive Program (this “Program”) is to promote the success of Edison International, a California corporation, (the “Corporation”), by motivating the executives selected to participate in this Program and set forth in Section 3.1 below (each, a “Participant”) to maximize the performance of the Corporation and rewarding them with cash bonuses directly related to such performance. This Program is intended to provide bonuses that qualify as performance-based compensation within the meaning of Section 162(m) (“Section 162(m)”) of the United States Internal Revenue Code of 1986, as amended (the “Code”). This Program is adopted under Section 5.2 of the Corporation’s 2007 Performance Incentive Plan (the “Plan”). Capitalized terms are defined in the Plan if not defined herein.

2. ADMINISTRATION

This Program shall be administered by the Compensation and Executive Personnel Committee of the Board (the “Committee”), which shall consist solely of two or more members of the Board who are “outside directors” within the meaning of Section 162(m). Action of the Committee with respect to the administration of this Program shall be taken pursuant to a majority vote or by the unanimous written consent of its members. The Committee shall have the authority to construe and interpret this Program and any agreements or other document relating to Awards under the Program, may adopt rules and regulations relating to the administration of this Program, and shall exercise all other duties and powers conferred on it by this Program. Any decision or action of the Committee within its authority hereunder shall be conclusive and binding upon all persons. Neither the Board nor the Committee, nor any person acting at the direction thereof, shall be liable for any act, omission, interpretation, construction or determination made in good faith in connection with this Program (or any Award made under this Program).

3. AWARDS

3.1 Award Grants; Maximum Annual Incentive Amount. Each “Award” granted to a Participant under this Program represents the opportunity to receive a cash payment determined under this Section 3 (an “Annual Incentive”), subject to the terms and conditions of this Program. The maximum amount of the Annual Incentive payable to each Participant (the “Maximum Annual Incentive Amount”) shall be determined by multiplying (i) the Annual Incentive Pool (as defined in Section 3.2 below), by (ii) the Participant’s “Annual Incentive Percentage” as set forth in the following table:

Participant	Annual Incentive Percentage
Ronald L. Litzinger	11%
John A. (Drew) Murphy	8%
Ronald Owen Nichols	7%
Kevin M. Payne	11%
Pedro J. Pizarro	40%
Maria C. Rigatti	12%
Adam S. Umanoff	11%

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In no case, however, shall the amount of any Annual Incentive exceed the applicable limit set forth in Section 5.2.3 of the Plan.

3.2 Annual Incentive Pool. As soon as practicable after the end of the Corporation’s 2017 fiscal year (the “Performance Period”), the Committee shall determine the amount of the Corporation’s earnings from continuing operations (after interest, taxes, depreciation and amortization, and determined on a consolidated basis) for the Performance Period (the “Performance Level”). The “Annual Incentive Pool” shall be determined by multiplying (i) the Performance Level, by (ii) one and one-half percent (1.5%). No Participant shall receive any payment under this Program unless and until the Committee has certified, by resolution or other appropriate action in writing, that the amount of the Performance Level has been accurately determined in accordance with the terms, conditions and limits of this Program and that any other material terms previously established by the Committee or set forth in this Program applicable to the Award were in fact satisfied.

3.3 Committee Discretion. Notwithstanding the foregoing provisions, the Committee shall retain discretion to reduce (but not increase) the Maximum Annual Incentive Amount otherwise payable to any one or more Participants pursuant to Sections 3.1 and 3.2. The Committee may exercise such discretion on any basis it deems appropriate (including, but not limited to, its assessment of the Corporation’s performance relative to its operating or strategic goals for the Performance Period and/or the Participant’s individual performance for such period). For purposes of clarity, if the Committee exercises its discretion to reduce the amount of any Annual Incentive payable hereunder, it may not allocate the amount of such reduction to Annual Incentives payable to other Participants.

3.4 Payment of Annual Incentives. Any Annual Incentives shall be paid as soon as practicable following the certification of the Committee’s findings under Section 3.2 and its determination of the final Annual Incentive amount (after giving effect to any exercise of its discretion to reduce Annual Incentives pursuant to Section 3.3) and in all events no later than March 15, 2018; in each case subject (i) to tax withholding pursuant to Section 4.6, and (ii) in the case of a Participant eligible to defer compensation under the EIX 2008 Executive Deferred Compensation Plan (the “EDCP”), to any timely deferral election the Participant may have made pursuant to the terms of the EDCP.

3.5 Termination of Employment.

(a) Except as provided in Section 3.5(b), in the event that a Participant’s employment with the Corporation and its Subsidiaries terminates at any time during the Performance Period, the Participant’s Award will immediately terminate upon such termination of employment, and the Participant will not be entitled to any Annual Incentive payment in respect of such Award; provided that the Committee may, in its discretion, award a full or partial Annual Incentive for the Performance Period to any Participant whose termination of employment during the Performance Period is due to the Participant’s death, permanent and total disability, or Retirement (with the amount of any such Bonus not to exceed the amount the Participant would have been entitled to had he or she remained employed for the entire Performance Period). For purposes of this Section 3.5, the term “Retirement” with respect to a Participant shall mean a termination of the Participant’s employment on or after the first day of the month in which the Participant (A) attains age 65 or (B) attains age 61 with five “years of service,” as that term is defined in the Edison 401(k) Savings Plan.

(b) In the event that the Participant’s employment with the Corporation and its Subsidiaries terminates during the Performance Period in circumstances that entitle the Participant to severance benefits pursuant to the Corporation’s 2008 Executive Severance Plan, and in such circumstances the Participant satisfies the applicable conditions for receiving severance benefits under that plan (including, without limitation, any requirement to execute and deliver a release of claims), then the provisions of this Section 3.5(b) shall control over Section 2.3.1(b) of the 2008 Executive Severance Plan to determine the Participant’s annual incentive for the year in which such termination of employment occurs. If a Participant’s Annual Incentive is to be determined pursuant to this Section 3.5(b), the Participant’s Annual Incentive shall equal the lesser of (A) or (B); where (A) isdetermined

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by multiplying (i) the Participant’s highest base salary rate in effect during the 24 months preceding the termination of the Participant’s employment, by (ii) the highest target annual incentive percentage in effect for the Participant during those 24 months, by (iii) a fraction (not greater than 1) the numerator of which is the number of weekdays in the Performance Period from January 1, 2017 through the Participant’s last day of employment prior to such termination and the denominator of which is the number of weekdays in the entire Performance Period; and (B) is determined by multiplying (i) the Participant’s Annual Incentive Percentage, by (ii) one and one-half percent (1.5%), by (iii) the Corporation’s earnings from continuing operations (after interest, taxes, depreciation and amortization, and determined on a consolidated basis) for the portion of the Performance Period through and ending on the last day of the month in which the Participant’s termination of employment occurs. In no case, however, shall the amount of any Annual Incentive exceed the applicable limit set forth in Section 5.2.3 of the Plan.

(c) No Participant shall receive any payment under this Section 3.5 unless and until the Committee has certified, by resolution or other appropriate action in writing, the amount of the Annual Incentive due in accordance with the terms, conditions and limits of this Program. Any Annual Incentive amount due pursuant to this Section 3.5 shall be paid as soon as practicable following the Committee’s certification of such amount and in all events no later than March 15, 2018; subject (i) to tax withholding pursuant to Section 4.6, and (ii) in the case of a Participant eligible to defer compensation under the EDCP, to any timely deferral election the Participant may have made pursuant to the terms of the EDCP.

3.6 Adjustments. The Committee shall make Adjustments (as defined below) to the Performance Level, Annual Incentive Pool and other provisions applicable to Awards granted under this Program to the extent (if any) it determines that such Adjustment is necessary to preserve the incentives and benefits intended at the time the Committee approved this Program.  “Adjustments” means: (1) excluding the impact of a change in tax rates and other aspects of comprehensive changes to tax laws or regulations; (2) excluding the dilutive effects of acquisitions or joint ventures; (3) assuming that any business divested by EIX or its subsidiaries achieved performance objectives at targeted levels during the balance of the performance period following such divestiture; (4) excluding the effect of any event or transaction referenced in Section 7.1 of the Plan; (5) excluding costs incurred in connection with potential acquisitions or divestitures that are required to be expensed under generally accepted accounting principles (“GAAP”); (6) excluding the effect of current-year costs recovered through litigation, arbitration, or mediation; (7) excluding the effects of changes to GAAP and changes in our accounting practices; and (8) mitigation of the unbudgeted impact of unusual or nonrecurring gains or losses, special charges, or other extraordinary events not foreseen at the time the Committee approved this Program.

3.7 Change in Control. If a Change in Control of EIX occurs at any time during the Performance Period, the Performance Period for all outstanding Awards will be shortened so that the Performance Period will be deemed to have ended on the last day prior to such Change in Control of EIX. The Annual Incentive Pool and the Annual Incentives payable with respect to each Award will be determined in accordance with the foregoing provisions of this Section 3 based on such shortened Performance Period. Such Annual Incentives shall be paid (subject to tax withholding pursuant to Section 4.6) as soon as practicable following the date of the Change in Control of EIX. For purposes of this Section 3.7, “Change in Control of EIX” shall have the meaning ascribed to such term in the Corporation’s 2017 Long-Term Incentives Terms and Conditions.

4. GENERAL PROVISIONS

4.1 Rights of Participants.

(a) No Right to Continued Employment. Nothing in this Program (or in any other documents evidencing any Award under this Program) will be deemed to confer on any Participant any right to continue in the employ of the Corporation or any Subsidiary or interfere in any way with the right of the Corporation or any Subsidiary to terminate his or her employment at any time.

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(b) Program Not Funded. No Participant or other person will have any right or claim to any specific funds, property or assets of the Corporation or any of its Subsidiaries by reason of any Award hereunder. To the extent that a Participant or other person acquires a right to receive payment pursuant to any Award hereunder, such right shall be no greater than the right of any unsecured general creditor of the Corporation (or applicable Subsidiary making such payment, as the case may be).

4.2 Non-Transferability of Benefits and Interests. Except as expressly provided by the Committee in accordance with the provisions of Section 162(m), all Awards are non-transferable, and no benefit payable under this Program shall be subject in any manner to sale, transfer, anticipation, alienation, assignment, pledge, encumbrance or charge. This Section 4.2 shall not apply to an assignment of a contingency or payment due (a) after the death of a Participant to the deceased Participant’s legal representative or beneficiary or (b) after the disability of a Participant to the disabled Participant’s personal representative.

4.3 Force and Effect. The various provisions herein are severable in their entirety. Any determination of invalidity or unenforceability of any one provision will have no effect on the continuing force and effect of the remaining provisions.

4.4 Governing Law. This Program will be construed under the laws of the State of California.

4.5 Construction. It is intended that Awards under this Program qualify as “short-term deferrals” within the meaning of the guidance provided by the Internal Revenue Service under Section 409A of the Code and this Program shall be interpreted consistent with that intent.

4.6 Tax Withholding. Upon the payment of any Annual Incentive, the Corporation (or applicable Subsidiary making such payment, as the case may be) shall have the right to deduct the amount of any federal, state or local taxes that the Corporation or any Subsidiary may be required to withhold with respect to such payment.

4.7 Amendment or Termination of Program. The Board or the Committee may at any time terminate, amend, modify or suspend this Program, in whole or in part. Notwithstanding the foregoing, no amendment may be effective without Board and/or shareholder approval if such approval is necessary to comply with the applicable rules of Section 162(m).

4.8 Claw-Back. Notwithstanding any provision of the Program to the contrary, the Program, any Award under the Program, and any payment of an Annual Incentive under the Program, shall be subject to any recoupment, “clawback” or similar provisions of applicable law, as well as the Corporation’s Incentive Compensation Clawback Policy, as in effect from time to time, and any other recoupment or similar policies of the Corporation that may be in effect from time to time.

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EX-10.2

Exhibit 10.2

EDISON INTERNATIONAL

2017 Long-Term Incentives

Terms and Conditions

1. LONG-TERM INCENTIVES

The long-term incentive awards granted in 2017 (“LTI”) for eligible persons (each, a “Holder”) employed by Edison International (“EIX”) or its participating affiliates include the following:

• Nonqualified stock options to purchase shares of EIX Common Stock (“EIX Options”) as described in Section 3;

• Contingent EIX performance units (“Performance Shares”) as described in Section 4; and

• Restricted EIX stock units (“Restricted Stock Units”) as described in Section 5.

Each of the LTI awards will be granted under the 2007 Performance Incentive Plan (the “Plan”) and will be subject to adjustment as provided in Section 7.1 of the Plan.

The LTI shall be subject to these 2017 Long-Term Incentives Terms and Conditions (these “Terms”). The LTI shall be administered by the Compensation and Executive Personnel Committee of the EIX Board of Directors (the “Committee”). The Committee shall have the administrative powers with respect to the LTI set forth in Section 3.2 of the Plan.

In the event EIX grants LTI to a Holder, the number of EIX Options, Performance Shares and Restricted Stock Units granted to the Holder will be set forth in a written award certificate delivered by EIX to the Holder.

2. VESTING OF LTI

Subject to Sections 8 and 9 the following vesting and payment rules shall apply to the LTI:

2.1 EIX Options. The EIX Options will vest over a four-year period as described in this Section 2 (the “Vesting Period”). The effective “initial vesting date” will be January 2, 2018, or six months after the date of the grant, whichever date is later. The EIX Options will vest as follows:

• On the initial vesting date, one-fourth of the award will vest.

• On January 2, 2019, an additional one-fourth of the award will vest.

• On January 2, 2020, an additional one-fourth of the award will vest.

• On January 4, 2021, the balance of the award will vest.

2.2 Performance Shares. The Performance Shares will vest and become payable to the extent earned as determined at the end of the three-calendar-year period commencing on January 1, 2017, and ending December 31, 2019 (the “Performance Period”), subject to the provisions of Section 4.

2.3 Restricted Stock Units. The Restricted Stock Units will vest and become payable on January 2, 2020.

2.4 Continuance of Employment/Service Required. The vesting schedule requires continued employment or service through each applicable vesting date as a condition for the vesting of the applicable installment of the LTI and the rights and benefits thereunder. Employment or service for only a portion of the vesting period, even if a substantial portion, will not entitle the Holder to any proportionate vesting or avoid or mitigate a termination of rights and benefits upon or following a termination of employment or services except as provided in Sections 8 and 9 below.

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3. EIX OPTIONS

3.1 Exercise Price. The exercise price of an EIX Option stated in the award certificate is the closing price (in regular trading) of a share of EIX Common Stock on the New York Stock Exchange for the effective date of the grant.

3.2 Cumulative Exercisability; Term of Option. The vested portions of the EIX Options will accumulate to the extent not exercised, and be exercisable by the Holder subject to the provisions of this Section 3 and Sections 8 and 9, in whole or in part, in any subsequent period but not later than January 4, 2027.

3.3 Method of Exercise. The Holder may exercise an EIX Option by providing written notice to EIX on the form prescribed by the Committee for this purpose, or completion of such other EIX Option exercise procedures as EIX may prescribe, accompanied by full payment of the applicable exercise price. Payment must be in cash or its equivalent acceptable to EIX. At the discretion of the Holder, EIX Common Stock valued on the exercise date at a per-share price equal to the closing price of EIX Common Stock on the New York Stock Exchange may be used to pay the exercise price, provided the Company can comply with any legal requirements. (“Companies” or “Company” means EIX and its affiliates, or any of them, as the context may require.) A broker-assisted “cashless” exercise may be accommodated for EIX Options at the discretion of EIX. Until payment is accepted, the Holder will have no rights in the optioned stock. The provisions of Section 10 must be satisfied as a condition precedent to the effectiveness of any purported exercise.

3.4 Automatic Exercise. Except as may otherwise be determined by the Committee in advance of the applicable exercise date and subject to the conditions below, the Holder’s then-outstanding vested EIX Options shall automatically be exercised by EIX on behalf of the Holder on the last day of the term of such options (including any shortened term as a result of a termination of employment or in connection with a Change in Control of EIX as provided in Articles 8 and 9), to the extent such options are not otherwise exercised on or before that date. In connection with any automatic exercise of outstanding vested EIX Options, EIX shall satisfy the exercise price of the EIX Options and the minimum applicable withholding obligation by withholding that number of EIX shares of Common Stock otherwise issuable pursuant to the options having a value (based on the closing price of EIX Common Stock on the New York Stock Exchange on the exercise date, or if no sales of EIX Common Stock were reported on the New York Stock Exchange on that date, the closing price of EIX Common Stock on the New York Stock Exchange on the next preceding day on which sales of EIX Common Stock were reported) equal to the exercise price of the EIX Options and the minimum applicable withholding obligation. Outstanding vested EIX Options shall only be automatically exercised by EIX on behalf of the Holder if (i) the EIX Options have an exercise price that is lower than the price of a share of EIX Common Stock on the New York Stock Exchange at the time of exercise so that the options are “in-the-money,” and (ii) the exercise by EIX complies with all legal requirements applicable to EIX.

4. PERFORMANCE SHARES

4.1 Performance Shares. Performance Shares are EIX Common Stock-based units subject to a performance vesting requirement. A target number of contingent Performance Shares will be awarded on the initial grant date. Fifty percent (50%) of the grant date value (based on EIX’s valuation methodology for the award) of the contingent Performance Shares will be a target number of contingent Performance Shares subject to a performance measure based on the percentile ranking of EIX total shareholder return (“TSR”) among the TSRs for the stocks comprising the Comparison Group (as defined below) over the entire Performance Period (these contingent Performance Shares are referred to as the “TSR Performance Shares”). The other fifty percent (50%) of the grant date value (based on EIX’s valuation methodology for the award) of the contingent Performance Shares will be a target number of contingent Performance Shares subject to a performance measure based on EIX’s average core earnings per share (“EPS”) over the entire Performance Period (these contingent Performance Shares are referred to as the “EPS Performance Shares”). The TSR Performance Shares and EPS Performance Shares will be increased by any additional Performance Shares created by “reinvestment” of dividend equivalents as provided in Section 4.5.

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4.2 TSR Performance Shares. The actual amount of TSR Performance Shares to be paid will depend on EIX’s TSR percentile ranking on the Performance Measurement Date (as defined herein). If EIX’s TSR is below the 25^th percentile, no TSR Performance Shares will be paid. Twenty-five percent (25%) of the target number of TSR Performance Shares will be paid if EIX’s TSR percentile ranking is at the 25^th percentile. The target number of TSR Performance Shares will be paid if EIX’s TSR rank is at the 50^th percentile. Two times the target number of TSR Performance Shares will be paid if EIX’s TSR percentile ranking is at the 75th percentile or higher. The payment multiple is interpolated for performance between the points indicated in the preceding three sentences on a straight-line basis with discrete intervals at every 5^th percentile.

TSR is calculated using (i) the average of the closing stock prices for the relevant stocks for the 20-trading-day period ending with the last day on which the New York Stock Exchange is open for trading preceding the first day of the Performance Period, and (ii) the average of the closing stock prices for the relevant stocks for the 20-trading-day period ending with the Performance Measurement Date. In making such determination, stock prices will be equitably and proportionately adjusted to the extent (if any) necessary to preserve the intended incentives of the awards and mitigate the impact of any stock split, stock dividend or reverse stock split occurring during the applicable period. The “Comparison Group” consists of the stocks comprising the Philadelphia Utility Index as the index is constituted on the Performance Measurement Date. If the Comparison Group consists of fewer than 20 stocks on the Performance Measurement Date, the stock with the median TSR for the entire Performance Period (or, if there are an even number of stocks in the Comparison Group before giving effect to this sentence, a stock deemed to have a TSR equal to the average TSR of the two stocks in the Comparison Group that fall in the middle of such group when ranked based on TSR for the entire Performance Period) shall be added back to the Comparison Group a sufficient number of times to bring the stocks comprising the Comparison Group to 20. (For purposes of clarity, if there are only 17 stocks in the Comparison Group before giving effect to the preceding sentence, the stock with the median TSR for the entire Performance Period will be added back to the Comparison Group a total of three times to bring the stocks comprising the Comparison Group to 20.) Dividends with ex-dividend dates falling inside the Performance Period will be included in the TSR calculations using the assumption that reinvestment occurs on the ex-dividend date.

The Performance Measurement Date for the TSR Performance Shares will be the last day of the Performance Period on which the New York Stock Exchange is open for trading. As of that date, the applicable payment multiple will be determined as provided above in this Section 4.2 based on the EIX TSR percentile ranking achieved during the Performance Period. No payment will be made with respect to the TSR Performance Shares unless and until the Committee has certified, by resolution or other appropriate action in writing, that the applicable EIX TSR percentile ranking has been accurately determined. The Committee shall not have discretion to pay TSR Performance Shares if the minimum EIX TSR ranking is not achieved or to pay TSR Performance Shares in excess of the amount provided above in this Section 4.2 for the applicable EIX TSR ranking.

4.3 EPS Performance Shares. The Committee shall establish an EIX EPS target for each of calendar 2017, 2018, and 2019, which are the three calendar years comprising the Performance Period. The Committee shall establish the EIX EPS target for each calendar year no later than during the first 90 days of the applicable calendar year, and while performance relating to the EIX EPS target remains substantially uncertain.

The actual amount of EPS Performance Shares to be paid will depend on EIX’s actual EPS performance achieved as a percentage of the EIX EPS target established for the calendar year. If EIX’s actual EPS for any calendar year is less than eighty percent (80%) of the EIX EPS target amount for the year, the EPS performance multiple for the calendar year will be zero (0). If EIX’s actual EPS for any calendar year is equal to eighty percent (80%) of the EIX EPS target amount for the year, the EPS performance multiple for the calendar year will be 0.25x. If EIX’s actual EPS for any calendar year is equal to one hundred percent (100%) of the EIX EPS target amount for the year, the EPS performance multiple for the calendar year will be 1.0x. If EIX’s actual EPS for any calendar year is equal to or greater than one hundred twenty percent (120%) of the EIX EPS target amount for the year, the EPS performance multiple for the calendar year will be 2.0x. Each year’s EPS performance multiple is interpolated for performance between the points indicated in the preceding three sentences on a straight-line basis with discrete intervals at every 4^th

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percentage point, however, the performance multiple will be equal to the lowest multiple within each interval.

Following the end of the Performance Period, the EPS performance multiples achieved for each of calendar 2017, 2018, and 2019 will be averaged (determined by including zero (0) for any year in which the EPS achieved was less than eighty percent (80%) of the applicable target for that year), and the resulting average EPS performance multiple achieved for the Performance Period is referred to as the “Performance Period EPS Multiple.” The actual amount of EPS Performance Shares to be paid will be determined by multiplying the Performance Period EPS Multiple times the target number of EPS Performance Shares.

EPS is defined as “Core” earnings per share, a non-GAAP financial measure derived from basic GAAP earnings per share by excluding income or loss from discontinued operations and income or loss from significant discrete items that are not representative of ongoing earnings. The Committee shall make Adjustments (as defined below) to the EPS target levels established and/or the level of EPS otherwise obtained for purposes of the EPS Performance Shares to the extent (if any) it determines that such Adjustment is necessary to preserve the incentives and benefits intended at the time the Committee established the applicable EPS target level for the applicable calendar year.  “Adjustments” means: (1) excluding the impact of a change in tax rates and other aspects of comprehensive changes to tax laws or regulations; (2) excluding the dilutive effects of acquisitions or joint ventures; (3) assuming that any business divested by EIX or its subsidiaries achieved performance objectives at targeted levels during the balance of the performance period following such divestiture; (4) excluding the effect of any event or transaction referenced in Section 7.1 of the Plan; (5) excluding costs incurred in connection with potential acquisitions or divestitures that are required to be expensed under GAAP; (6) excluding the effect of current-year costs recovered through litigation, arbitration, or mediation; (7) excluding the effects of changes to GAAP and changes in our accounting practices with respect to non-GAAP items; and (8) mitigation of the unbudgeted impact of unusual or nonrecurring gains or losses, or other extraordinary events not foreseen at the time the Committee established the applicable EPS target level. “GAAP” means generally accepted accounting principles.

For purposes of Section 162(m) of the Code, each of calendar years 2017, 2018, and 2019 shall be treated as a separate performance period and the EIX EPS target established for each such year shall be treated as a separate performance goal. If EIX’s actual EPS for any calendar year is equal to eighty percent (80%) or more of the EIX EPS target amount for the year (the “EPS Performance Threshold”), then the maximum total EPS Performance Share payment (including any additional EPS Performance Shares created by “reinvestment” of dividend equivalents as provided in Section 4.5) may not exceed the lesser of (1) two hundred and fifty percent (250%) times the target number of EPS Performance Shares or (2) the maximum share limit specified in Section 5.2.3 of the Plan (such maximum payment, the “EPS Maximum Payment”), and the actual payment amount determined as set forth above is a reduction of the payment below the EPS Maximum Payment. No payment will be made with respect to the EPS Performance Shares unless and until the Committee has certified, by resolution or other appropriate action in writing, that the EPS Performance Threshold has been achieved. The Committee shall not have discretion to pay EPS Performance Shares if the EPS Performance Threshold is not achieved or to pay EPS Performance Shares in excess of the EPS Maximum Payment.

4.4 Payment of Performance Shares. The total number of Performance Shares that are earned pursuant to Sections 4.2, 4.3, and 4.5 will be paid in cash. The value of each whole Performance Share paid in cash will be equal to the closing price per share of EIX Common Stock on the New York Stock Exchange for the date of the Committee’s certification in Section 4.2 and Section 4.3 above, and the value of any fractional Performance Share paid in cash will also be determined based on that price. The cash payable for the earned Performance Shares will be delivered as soon as practicable for EIX following the Committee’s certification in Section 4.2 and Section 4.3 above, as applicable, and in all events no later than March 15, 2020. The Performance Shares are subject to termination and other conditions specified in Sections 8 and 9, and to the provisions of Section 10.

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4.5 Dividend Equivalent Reinvestment. For each dividend on EIX Common Stock for which the ex-dividend date falls within the Performance Period and after the date of grant of the Performance Shares, the Holder of the Performance Shares will be credited with an additional number of target Performance Shares. The additional number of shares added on each ex-dividend date will be equal to (i) the per-share cash dividend paid by EIX on its Common Stock with respect to the related ex-dividend date, multiplied by (ii) the Holder’s number of target Performance Shares (including any additional target Performance Shares previously credited under this Section 4.5), divided by (iii) the closing price of a share of EIX Common Stock on the related ex-dividend date, with the result rounded to six decimal places. Any target Performance Shares added pursuant to the foregoing provisions of this Section 4.5 will be subject to the same vesting, payment, termination and other terms, conditions and restrictions as the original target Performance Shares to which they relate (including, as applicable, application of the TSR payment multiple as contemplated by Section 4.2 or the EPS performance payment multiple as contemplated by Section 4.3). No target Performance Shares will be added pursuant to this Section 4.5 with respect to any target Performance Shares which, as of the related ex-dividend date, have either become payable pursuant to Section 4.4 or terminated pursuant to Section 8.

5. RESTRICTED STOCK UNITS

5.1 Restricted Stock Units. Restricted Stock Units are EIX Common Stock-based units that vest based on the passage of time. As soon as practicable for EIX following January 2, 2020 (and in all events within 90 days after such date), EIX will pay Restricted Stock Units that have vested, except that if the Restricted Stock Units vest pursuant to Section 8.2, 8.3, 8.4, 8.5 or 9, the Restricted Stock Units will become payable as provided in the applicable section below and as follows. Whole Restricted Stock Units that have vested will be paid on a one-for-one basis in EIX Common Stock under the Plan. Any fractional Restricted Stock Unit will be paid in cash based on the closing price per share of EIX Common Stock on January 2, 2020 or, as to any fractional Restricted Stock Units that have vested pursuant to Section 8.3, 8.4, 8.5 or 9 (including any payment made pursuant to Section 14.7, but excluding any payment where the time for payment is determined by reference to Section 8.2(C)), the closing price per share of EIX Common Stock on the New York Stock Exchange for the business day immediately preceding the day of payment. The Restricted Stock Units are subject to termination and other conditions specified in Sections 8 and 9, and to the provisions of Section 10.

5.2 Dividend Equivalent Reinvestment. For each dividend declared on EIX Common Stock with an ex-dividend date on or after the date an award of Restricted Stock Units is granted and before all of such Restricted Stock Units either have been paid (or converted into a cash amount, as the case may be) pursuant to Section 5.1 (including any payment made pursuant to Section 14.7) or have terminated pursuant to Section 8 or 9, the Holder of such award will be credited with an additional number of Restricted Stock Units equal to (i) the per-share cash dividend paid by EIX on its Common Stock with respect to the related ex-dividend date, multiplied by (ii) the total number of outstanding and unpaid Restricted Stock Units (including any Restricted Stock Units previously credited under this Section 5.2) subject to such award as of such ex-dividend date, divided by (iii) the closing price of a share of EIX Common Stock on the related ex-dividend date, with the result rounded to six decimal places. Any additional Restricted Stock Units credited pursuant to the foregoing provisions of this Section 5.2 will be subject to the same vesting, payment, termination and other terms, conditions and restrictions as the original Restricted Stock Units to which they relate; provided, however, that the Committee shall retain discretion to pay any Restricted Stock Units in cash rather than shares of EIX Common Stock if and to the extent that payment in shares would exceed the applicable share limits of the Plan. No crediting of Restricted Stock Units will be made pursuant to this Section 5.2 with respect to any Restricted Stock Units which, as of the related ex-dividend date, have either been paid pursuant to Section 5.1 or terminated pursuant to Section 8 or 9.

6. DELAYED PAYMENT OR DELIVERY OF LTI GAINS

Notwithstanding any other provision herein, Holders who are eligible to defer salary under the EIX 2008 Executive Deferred Compensation Plan (the “EDCP”) may irrevocably elect to defer receipt of all or a part of the cash payable in respect of their earned Performance Shares pursuant to the terms of the EDCP. To make such an election, the Holder must submit a signed agreement in the form approved by, and in advance of the applicable deadline established

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by, the Committee. In the event of any timely deferral election, the LTI with respect to which the deferral election was made shall be paid in accordance with the terms of the EDCP.

7. TRANSFER AND BENEFICIARY

7.1 Limitations on Transfers. Except as provided below and in Section 10, the LTI will not be transferable by the Holder and, during the lifetime of the Holder, the LTI will be exercisable only by him or her. The Holder may designate a beneficiary who, upon the death of the Holder, will be entitled to exercise the then vested portion of the LTI during the remaining term subject to the provisions of the Plan and these Terms.

7.2 Exceptions. Notwithstanding the foregoing, the LTI of the most senior officer of EIX, the most senior officer of Southern California Edison Company (“SCE”), the most senior officer of Edison Energy, Inc. (“EEG”), the General Counsel of EIX, and the Chief Financial Officer of EIX, are transferable to a spouse, children or grandchildren, or trusts or other vehicles established exclusively for their benefit. Any transfer request must specifically be authorized by EIX in writing and shall be subject to any conditions, restrictions or requirements as the Committee may determine. Restricted Stock Units may not, however, be transferred to the extent the transfer would violate (and result in any tax, penalty or interest under) Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”).

8. TERMINATION OF EMPLOYMENT

8.1 General. In the event of termination of the employment of the Holder for any reason other than those specified in Sections 8.2, 8.3, 8.4 or 9, the LTI will terminate as follows: (i) the Holder’s unvested EIX Options will terminate for no value as of the date such employment terminates, (ii) the Holder’s vested EIX Options will terminate for no value 180 days from the date on which such employment terminated (or, if earlier, on the last day of the applicable EIX Option term) to the extent not theretofore exercised, (iii) the Holder’s unearned Performance Shares will terminate for no value as of the date such employment terminates, and (iv) the Holder’s unvested Restricted Stock Units will terminate for no value as of the date such employment terminates. Any fractional vested EIX Options will be rounded up to the next whole share.

8.2 Retirement. If the Holder terminates employment on or after the first day of the month in which he or she (i) attains age 65 or (ii) attains age 61 with five “years of service,” as that term is defined in the Edison 401(k) Savings Plan (a “Retirement”), then the vesting and exercise or payment provisions of this Section 8.2 will apply.

(A) EIX Options. The EIX Options will remain outstanding and eligible to vest; provided, however, that in the event the Holder’s Retirement occurs within calendar 2017, the portion of the option that remains outstanding and eligible to vest following the Holder’s Retirement will be prorated by multiplying the total number of shares subject to the option by a fraction (not greater than 1), the numerator of which shall be the number of whole months in calendar 2017 that the Holder was employed by one or more of the Companies, and the denominator of which shall be twelve (12). In no event shall the Holder be credited with services performed during any portion of a calendar month (even if a substantial portion) if the Holder is not employed by one or more of the Companies as of the last day of such calendar month. The portion of the option not eligible to vest following the Holder’s Retirement after giving effect to the proration described in the preceding two sentences shall terminate as of the Holder’s Retirement, and the Holder shall have no further rights with respect to such terminated portion. Any fractional EIX Options eligible to vest under this Section 8.2 will be rounded up to the next whole number. EIX Options that remain outstanding and eligible to vest following Retirement will vest and become exercisable on the schedule under which they would have been vested had the Holder not retired (one-fourth of the option grant on the effective initial vesting date (January 2, 2018 or six months after the date of grant, whichever is later) and an additional one-fourth on each of January 2, 2019, January 2, 2020 and January 4, 2021), except that if the Holder dies, the then-outstanding portion of the option will immediately vest and become exercisable as of the date of the Holder’s death. In the event prorated vesting is required in connection with the Holder’s Retirement, the portion of the option that remains outstanding and eligible to vest will vest and become exercisable first on the effective initial vesting date (up to the maximum number of

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shares that would have vested and become exercisable on that date had no termination of employment occurred) and so on until the portion of the option that remains outstanding and eligible to vest becomes vested and exercisable, except that if the Holder dies, the then-outstanding portion of the option will immediately vest and become exercisable as of the date of the Holder’s death. Once exercisable, EIX Options will remain exercisable as provided in Section 3 for the remainder of the original EIX Option term.

(B) Performance Shares. The Performance Shares will vest and become payable at the end of the Performance Period to the extent they would have vested and become payable if the Holder’s employment had continued through the last day of the Performance Period; provided, however, that if the Holder’s Retirement occurs within calendar 2017, the number of each of the TSR Performance Shares and EPS Performance Shares that remain outstanding and eligible to vest following the Holder’s Retirement will be prorated by multiplying the number of TSR Performance Shares or EPS Performance Shares, respectively, subject to the award by a fraction (not greater than 1), the numerator of which shall be the number of whole months in calendar 2017 that the Holder was employed by one or more of the Companies, and the denominator of which shall be twelve (12). For this purpose, the number of “whole months” shall be calculated as provided in Section 8.2(A) above. Performance Shares will be payable to the Holder on the payment date specified in Section 4.4 to the extent, as applicable, of the EIX TSR ranking achieved as specified in Section 4.2 or the Performance Period EPS Multiple achieved as specified in Section 4.3. Any unvested Performance Shares (after application of the foregoing vesting provisions) will terminate for no value.

(C) Restricted Stock Units. The Restricted Stock Units will remain outstanding and eligible to vest following the Holder’s Retirement and will vest and be payable on or as soon as practicable for EIX following January 2, 2020 (and in all events within 90 days after such date); provided, however, that in the event the Holder’s termination of employment occurs within calendar 2017, the number of Restricted Stock Units that remain outstanding and eligible to vest following the Holder’s Retirement will be prorated by multiplying the total number of Restricted Stock Units subject to the award by a fraction (not greater than 1), the numerator of which shall be the number of whole months in calendar 2017 that the Holder was employed by one or more of the Companies, and the denominator of which shall be twelve (12). For this purpose, the number of “whole months” shall be calculated as provided in Section 8.2(A) above. Any Restricted Stock Units not eligible to vest following the Holder’s Retirement (after application of the foregoing vesting provisions) will terminate for no value. Notwithstanding the foregoing provisions, if the Holder dies after Retirement and prior to the date the then outstanding Restricted Stock Units are paid, the then outstanding Restricted Stock Units will vest and be paid as soon as practicable for EIX (and in all events within 90 days) following the date of the Holder’s death.

8.3 Death or Disability. If, prior to the Holder’s termination of employment with a Company, the Holder dies or incurs a “disability” (as such term is defined for purposes of Section 409A of the Code), the provisions of this Section 8.3 will apply.

(A) EIX Options. Any unvested EIX Options will immediately vest. The EIX Options will be exercisable immediately as of the date of such termination and will remain exercisable as provided in Section 3 for the remainder of the original EIX Option term.

(B) Performance Shares. The Performance Shares will vest and become payable at the end of the Performance Period as provided in Section 4.4 to the extent they would have vested and become payable if the Holder’s employment had continued through the last day of the Performance Period.

(C) Restricted Stock Units. Any unvested Restricted Stock Units will immediately vest and become payable as soon as practicable for EIX (and in all events within 90 days) after the date of the Holder’s death or disability, as applicable.

8.4 Involuntary Termination Not for Cause. Except as may otherwise be provided in Section 9, upon involuntary termination of the Holder’s employment by his or her employer not for cause (and other than due to the Holder’s death or disability), the provisions of this Section 8.4 shall apply.

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(A) EIX Options. Unvested EIX Options will vest to the extent necessary to cause the aggregate number of shares subject to vested EIX Options (including any shares acquired pursuant to previously exercised EIX Options) to equal the number of shares granted multiplied by a fraction (not greater than 1), the numerator of which is the number of whole months in the period from January 1 of the year of grant of the award through the one-year anniversary of the Holder’s last day of employment prior to termination of the Holder’s employment, and the denominator of which is forty-eight (48). For purposes of determining such fraction, no fractional month shall be taken into account. The Holder will have one year following the date of termination in which to exercise the EIX Options, or until the end of the EIX Option term, whichever occurs earlier. The Holder’s vested options will terminate for no value at the end of such period to the extent not theretofore exercised. The portion of the option not eligible to vest following the termination of the Holder’s employment after giving effect to the proration described in this Section 8.4(A) shall terminate as of the termination of the Holder’s employment, and the Holder shall have no further rights with respect to such terminated portion. Any fractional EIX Options vested under this Section 8.4(A) will be rounded up to the next whole number.

Notwithstanding anything to the contrary in the preceding paragraph, if the Holder qualifies for Retirement (as defined in Section 8.2) at the time of the termination of the Holder’s employment, or if the Holder would have satisfied the requirements for Retirement if an extra year of service and age were applied, EIX Options will (i) vest (without any proration) and become exercisable on the schedule specified in Section 8.2 and (ii) remain exercisable for the remainder of the original EIX Option term.

(B) Performance Shares. The Performance Shares will vest and become payable at the end of the Performance Period to the extent they would have vested and become payable if the Holder’s employment had continued through the last day of the Performance Period; provided, however, that the number of each of the TSR Performance Shares and EPS Performance Shares that remain outstanding and eligible to vest following termination of the Holder’s employment will be prorated by multiplying the number of TSR Performance Shares or EPS Performance Shares, respectively, subject to the award by a fraction (not greater than 1), the numerator of which shall be the number of whole months the Holder was employed by one or more of the Companies from January 1, 2017 through the one-year anniversary of the Holder’s last day of employment prior to termination of the Holder’s employment, and the denominator of which is thirty-six (36). For purposes of determining such fraction, no fractional month shall be taken into account. Such vested Performance Shares will be payable to the Holder as provided in Section 4.4 to the extent, as applicable, of the EIX TSR ranking achieved as provided in Section 4.2 or the Performance Period EPS Multiple achieved as specified in Section 4.3. Any unvested Performance Shares (after application of the foregoing vesting provisions) will terminate for no value as of the date of the Holder’s termination of employment.

Notwithstanding anything to the contrary in the preceding paragraph, if the Holder qualifies for Retirement (as defined in Section 8.2) at the time of the termination of the Holder’s employment, or if the Holder would have satisfied the requirements for Retirement if an extra year of service and age were applied, the Performance Shares will vest (without proration) and become payable at the end of the Performance Period as provided in Section 4.4 to the extent they would have vested and become payable if the Holder’s employment had continued through the last day of the Performance Period.

(C) Restricted Stock Units. The Restricted Stock Units will vest to the extent necessary to cause the aggregate number of vested Restricted Stock Units to equal the number of Restricted Stock Units subject to the award multiplied by a fraction (not greater than 1), the numerator of which is the number of whole months in the period from January 1 of the year of grant of the award through the one-year anniversary of the Holder’s last day of employment prior to termination of the Holder’s employment, and the denominator of which is thirty-six (36). For purposes of determining such fraction, no fractional month shall be taken into account. Any unvested Restricted Stock Units (after application of the foregoing vesting provisions) will terminate for no value as of the date of the Holder’s termination of employment. Subject to the last paragraph of this Section 8.4(C), vested Restricted Stock Units will be paid as soon as practicable for EIX (and in all events within 90 days) following the date of the Holder’s Separation from Service, if the

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Separation from Service occurs prior to any other applicable payment event otherwise provided for in these Terms. For purposes of the LTI, a “Separation from Service” means the Holder’s “separation from service” with the Company as that term is used for purposes of Section 409A of the Code.

Notwithstanding anything to the contrary in the preceding paragraph, if the Holder qualifies for Retirement (as defined in Section 8.2) at the time of the termination of the Holder’s employment, the Restricted Stock Units will vest (without any proration) and become payable at the same time provided for in Section 8.2(C).

In addition, and notwithstanding anything to the contrary in the preceding two paragraphs, if the Holder does not qualify for Retirement at the time of the termination of the Holder’s employment, but the Holder would have satisfied the requirements for Retirement if an extra year of service and age had been applied at the time of termination, then the Restricted Stock Units (i) will vest (without any proration) and (ii) will, subject to the last paragraph of this Section 8.4(C), become payable as soon as practicable for EIX (and in all events within 90 days) following the date of the Holder’s Separation from Service, if the Separation from Service occurs prior to any other applicable payment event otherwise provided for in these Terms.

If either the first or third paragraphs of this Section 8.4(C) apply and the period for payment of the Restricted Stock Units spans two calendar years, and if Section 8.4(D) applies and the period for delivery of the Holder’s release of claims and any applicable revocation period also spans those two calendar years, then the payment of the applicable Restricted Stock Units will be made (subject to the satisfaction of Section 8.4(D)) within the prescribed period of time but in the second of those two calendar years.

(D) Conditions of Benefits. Notwithstanding the foregoing provisions, if at the time of the Holder’s involuntary termination the Holder is covered by a severance plan of EIX or any of its affiliates, the Holder shall be entitled to the accelerated vesting provided in this Section 8.4 only if the Holder satisfies the applicable conditions for receiving severance benefits under that plan (including, without limitation, any requirement to execute and deliver a release of claims) in connection with such involuntary termination. In the event that such conditions are not satisfied, the provisions of Section 8.1 above shall apply, and the Holder shall not be entitled to any accelerated vesting under this Section 8.4.

8.5 Effect of Change of Employer. For purposes of the LTI only, involuntary termination of employment will be deemed to occur on the date the Holder’s employing company is no longer a member of the EIX controlled group of corporations as defined in Section 1563(a) of the Code, regardless of whether the Holder’s employment continues with that entity or a successor entity outside of the EIX controlled group. A termination of employment will not be deemed to occur for purposes of the LTI if a Holder’s employment by one EIX Company terminates but immediately thereafter the Holder is employed by another EIX Company.

9. CHANGE IN CONTROL; EARLY TERMINATION OF LTI

Notwithstanding any other provision herein, in the event of a Change in Control of EIX (as defined in Section 9.6), the provisions of this Section 9 will apply.

9.1 EIX Options. In the event the EIX Options are to terminate pursuant to Section 7.2 of the Plan in connection with a Change in Control of EIX, then upon (or, as may be necessary to effect the acceleration, immediately prior to) the Change in Control of EIX the then-outstanding and unvested EIX Options will become fully vested; provided, however, that this automatic acceleration provision will not apply with respect to any EIX Options to the extent the Committee has made a provision for the substitution, assumption, exchange or other continuation of the EIX Options. In the event of such a termination where the Committee has not provided for a cash settlement of the EIX Options as described below, the Holder of each EIX Option that is to be so terminated will be given reasonable advance notice of the impending termination and a reasonable opportunity to exercise such EIX Option in accordance with its terms before such termination (except that in no event will more than 10 days’ notice of the accelerated vesting and impending termination be required). The Committee may provide, as to each EIX Option that is to be terminated in connection with a Change in Control of EIX, to settle the EIX Option by a cash payment to the Holder of such option based upon the distribution or

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consideration payable to the holders of the EIX Common Stock upon or in respect of such event, such cash payment to be made as soon as practicable for EIX after the Change in Control of EIX.

9.2 Performance Shares. In the event the Performance Shares are to terminate pursuant to Section 7.2 of the Plan in connection with a Change in Control of EIX, then the Performance Period for all outstanding Performance Shares will be shortened so that the Performance Period will be deemed to have ended on the last day prior to such Change in Control of EIX, and the Performance Shares that will vest and become payable will be determined in accordance with Section 4.2 (TSR Performance Shares) or 4.3 (EPS Performance Shares) based on such shortened Performance Period (and, with respect to the EPS Performance Shares, after giving effect to a proportionate adjustment by the Committee to the EIX EPS target established for the year in which the Change in Control of EIX occurs to pro-rate such target for the portion of such year elapsed through the last day prior to such Change in Control of EIX); provided, however, that this automatic acceleration provision will not apply with respect to any Performance Shares to the extent the Committee has made a provision for the substitution, assumption, exchange or other continuation of the Performance Shares. Any Performance Shares that become subject to a shortened Performance Period pursuant to this Section 9.2 shall be paid, to the extent such Performance Shares become vested and payable after giving effect to the first sentence of this Section 9.2, to the Holder in cash as soon as practicable for EIX (and in all events within 74 days ) after the date of the Change in Control of EIX, and any such Performance Shares that do not become vested and payable shall terminate for no value as of the date of the Change in Control of EIX.

9.3 Restricted Stock Units. This Section 9.3 applies to the Restricted Stock Units notwithstanding anything to the contrary in Section 7.2 of the Plan. The Committee may not exercise any discretion to change the payment date(s) of the Restricted Stock Units except as otherwise expressly provided in this Section 9.3 or as otherwise compliant with (so as to not result in any tax, penalty or interest under) Section 409A of the Code. The Restricted Stock Units may only be terminated in connection with a Change in Control of EIX to the extent the termination satisfies the requirements of Treasury Regulation Section 1.409A-3(j)4(ix) (Plan Terminations and Liquidations). In the event the Restricted Stock Units are to terminate in connection with such an event, then upon (or, as may be necessary to effect the acceleration, immediately prior to) the Change in Control of EIX, the then-outstanding and unvested Restricted Stock Units will become fully vested. In the event the Restricted Stock Units are not to be so terminated in connection with such an event, the Committee shall make provision for the substitution, assumption, exchange or other continuation of the Restricted Stock Units in a manner that is compliant with (and does not result in any tax, penalty or interest under) Section 409A of the Code and the Restricted Stock Units shall be paid at the first applicable time otherwise provided in these Terms.

9.4 Severance Plan Benefits. If a Holder is a participant in the EIX 2008 Executive Severance Plan (or any similar successor plan) and experiences a Qualifying Termination Event as defined in the EIX 2008 Executive Severance Plan (or a similar employment termination under a successor plan) associated with a Change in Control as defined in the EIX 2008 Executive Severance Plan (or any similar successor plan), then (i) the Holder’s outstanding EIX Options will immediately vest, (ii) the Holder will have two years following the date of termination in which to exercise such EIX options if the Holder is a Senior Vice President or an officer of higher rank of EIX, SCE, or EEG (three years if the Holder is the most senior officer of EIX, the most senior officer of SCE, the most senior officer of EEG, the General Counsel of EIX, or the Chief Financial Officer of EIX), in each case subject to earlier termination at the end of the applicable option term or as provided in Section 9.1 above, (iii) any then outstanding Performance Shares shall be treated as provided for in Section 8.3(B) above, if the applicable performance period has not been shortened pursuant to Section 9.2 above, and (iv) any then outstanding Restricted Stock Units will immediately and fully vest, and will be paid as soon as practicable for EIX (and in all events within 90 days) following the date of the Holder’s Separation from Service, if vesting had not otherwise been triggered by Section 9.3 above.

9.5 Other Acceleration Rules. Any acceleration of LTI pursuant to this Section 9 will comply with applicable legal requirements and, if necessary to accomplish the purposes of the acceleration or if the circumstances require, may be deemed by the Committee to occur within a limited period of time not greater than 30 days prior to the Change in Control of EIX. Without limiting the generality of the foregoing, the Committee may deem an acceleration to occur immediately prior to the applicable event and/or reinstate the original terms of a LTI if the event giving rise to acceleration does not occur.

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9.6 Definition of Change in Control of EIX. A “Change in Control of EIX” shall be deemed to have occurred as of the first day, after the date of grant, that any one or more of the following conditions shall have been satisfied:

(A) Any Person (other than a trustee or other fiduciary holding securities under an employee benefit plan of EIX) becomes the Beneficial Owner, directly or indirectly, of securities of EIX representing thirty percent (30%) or more of the combined voting power of EIX’s then outstanding securities. For purposes of this clause, “Person” shall mean any individual, entity or group (within the meaning of Section 13(d)(3) or 14(d)(2) of the Exchange Act, except that such term shall not include one or more underwriters acquiring newly-issued voting securities (or securities convertible into voting securities) directly from EIX with a view towards distribution; and the term “Beneficial Owner” shall mean as defined under Rule 13d-3 promulgated under the Exchange Act.

(B) On any day after the date of grant (the “Reference Date”) Continuing Directors cease for any reason to constitute a majority of the EIX Board of Directors (the “Board”). A director is a “Continuing Director” if he or she either:

(i) was a member of the Board on the applicable Initial Date (an “Initial Director”); or

(ii) was elected to the Board, or was nominated for election by EIX’s shareholders, by a vote of at least two-thirds (2/3) of the Initial Directors then in office.

A member of the Board who was not a director on the applicable Initial Date shall be deemed to be an Initial Director for purposes of clause (b) above if his or her election, or nomination for election by EIX’s shareholders, was approved by a vote of at least two-thirds (2/3) of the Initial Directors (including directors elected after the applicable Initial Date who are deemed to be Initial Directors by application of this provision) then in office. For these purposes, “Initial Date” means the later of (A) the date of grant or (B) the date that is two (2) years before the Reference Date.

(C) EIX is liquidated; all or substantially all of EIX’s assets are sold in one or a series of related transactions; or EIX is merged, consolidated, or reorganized with or involving any other corporation, other than a merger, consolidation, or reorganization that results in the voting securities of EIX outstanding immediately prior thereto continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity) more than fifty percent (50%) of the combined voting power of the voting securities of EIX (or such surviving entity) outstanding immediately after such merger, consolidation, or reorganization. Notwithstanding the foregoing, a bankruptcy of EIX or a sale or spin-off of an affiliate of EIX (short of a dissolution of EIX or a liquidation of substantially all of EIX’s assets, determined on an aggregate basis) will not constitute a Change in Control of EIX.

(D) The consummation of such other transaction that the Board may, in its discretion in the circumstances, declare to be a Change in Control of EIX for purposes of the Plan.

10. TAXES AND OTHER WITHHOLDING

Upon any exercise, vesting, payment or other taxable event with respect to any LTI, the Company shall have the right at its option to:

• require the Holder (or the Holder’s personal representative or beneficiary, as the case may be) to pay or provide for payment of the amount of any taxes which the Company may be required to withhold with respect to such LTI event or payment; or

• deduct from any amount otherwise payable in cash to the Holder (or the Holder’s personal representative or beneficiary, as the case may be), with respect to any LTI or otherwise, the amount of any taxes which the Company may be required to withhold.

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To the extent that the payment of any LTI pursuant to exercise or vesting requires tax withholding and a sufficient amount of cash (not otherwise deferred) is not generated from the underlying transaction to satisfy such withholding obligations, EIX shall substitute a cash award for a number of shares of Common Stock otherwise issuable pursuant to the LTI, rounded up to the next whole share for fractional shares and valued in a consistent manner at their fair market value as of the date of such exercise (in the case of EIX Options) or (in the case of Restricted Stock Units) at a fair market value based on the closing price per share of EIX Common Stock on January 2, 2020 (or, as to any Restricted Stock Units that have vested pursuant to Section 8.3, 8.4, 8.5 or 9 (including any payment made pursuant to Section 14.7, but excluding any payment where the time for payment is determined by reference to Section 8.2(C)), the closing price per share of EIX Common Stock on the New York Stock Exchange for the business day immediately preceding the day of payment), as is necessary to satisfy the applicable withholding obligation in connection with such transaction to the extent that such withholding amount exceeds the amount of cash generated from the underlying transaction and not otherwise deferred.

If for any reason EIX cannot or elects not to satisfy such withholding obligations in such manner, or if a tax withholding obligation arises in any other circumstances, the Company shall have the right to satisfy such withholding obligations, or require the Holder to satisfy such withholding obligations, as otherwise provided above.

To the extent that the payment of any LTI pursuant to exercise or vesting requires Garnishment Payments by the Company, and a sufficient amount of cash is not generated by the underlying transaction to satisfy the Garnishment Payment obligations arising from such transaction, the Company shall substitute a cash award for a number of shares of Common Stock otherwise issuable pursuant to the LTI, rounded up to the next whole share for fractional shares and valued in a consistent manner at their fair market value as of the date of such exercise (in the case of EIX Options) or (in the case of Restricted Stock Units) at a fair market value based on the closing price per share of EIX Common Stock on the New York Stock Exchange for January 2, 2020 (or, as to any Restricted Stock Units that have vested pursuant to Section 8.3, 8.4, 8.5 or 9 (including any payment made pursuant to Section 14.7, but excluding any payment where the time for payment is determined by reference to Section 8.2(C)), the closing price per share of EIX Common Stock on the New York Stock Exchange for the business day immediately preceding the day of payment), equal to the amount required by any Garnishment, less any cash received and not deferred in connection with such transaction. For this purpose, “Garnishment” means garnishment orders, levies, and other assessments imposed by legal authority and “Garnishment Payments” means payments required by the Company pursuant to any such Garnishment.

11. CONTINUED EMPLOYMENT

Nothing in the award certificate or these Terms will be deemed to confer on the Holder any right to continue in the employ of EIX, any of its subsidiaries, or any other entity or interfere in any way with the right of any of them to terminate his or her employment at any time.

12. INSIDER TRADING; SECTION 16

12.1 Insider Trading. Each Holder shall comply with all EIX notice, trading and other policies regarding transactions in and involving EIX securities (including, without limitation, policies prohibiting insider trading).

12.2 Section 16. If an LTI is granted to a person who later becomes subject to the provisions of Section 16 of the Exchange Act (“Section 16”) in respect of EIX, the LTI will immediately and automatically become subject to the requirements of Rule 16b-3(d) and/or 16b-3(e) ( the “Rule”) and may not be exercised, transferred or (to the extent permitted by Section 409A of the Code without triggering any tax, penalty or interest thereunder) paid until the Rule has been satisfied. Approval of these Terms is intended to satisfy the Rule. However, in its sole discretion, the Committee may take any other action to assure compliance with the requirements of the Rule, including (to the extent permitted by Section 409A of the Code without triggering any tax, penalty or interest thereunder) withholding delivery to Holder (or any other person) of any security or of any other payment in any form until the requirements of the Rule have been satisfied. The Secretary of EIX may waive compliance with the requirements of the Rule if he or she determines the transaction to be exempt from the provisions of paragraph (b) of Section 16.

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12.3 Notice of Disposition. The Holder agrees that if he or she should plan to dispose of any shares of stock acquired on the exercise or payment of LTI awards (including a disposition by sale, exchange, gift or transfer of legal title) and the Holder is a person who is required to preclear EIX securities transactions, the Holder will notify EIX prior to such disposition.

13. AMENDMENT

The LTI are subject to the terms of the Plan, as it may be amended from time to time. EIX reserves the right to amend these Terms from time to time to the extent that EIX reasonably determines that the amendment is necessary or advisable to comply with applicable laws, rules or regulations or to preserve the intended tax consequences of the applicable LTI. The LTI may not otherwise be amended or terminated (by amendment to or of the Plan or otherwise) in any manner materially adverse to the rights of the Holder of the affected LTI without such Holder’s consent.

14. MISCELLANEOUS

14.1 Force and Effect. The various provisions herein are severable in their entirety. Any determination of invalidity or unenforceability of any one provision will have no effect on the continuing force and effect of the remaining provisions.

14.2 Governing Law.These Terms will be construed under the laws of the State of California.

14.3 Notice.Unless waived by EIX, any notice required under or relating to the LTI must be in writing, with postage prepaid, addressed to: Edison International, Attn: Corporate Secretary, P.O. Box 800, Rosemead, CA 91770.

14.4 Construction.These Terms shall be construed and interpreted to comply with Section 409A of the Code. Additionally, when any provision of this document refers to a date, including a date implied by the end of a specified period, and that date falls on a holiday or weekend, the date shall be deemed to be the immediately preceding business day on which the New York Stock Exchange is open, except that the last day of the Performance Period shall occur on December 31, 2019 and in no event shall the term of an EIX Option extend beyond its maximum 10-year term. Any determination of trading price or fair market value for purposes of these Terms shall be made consistent with the resolutions adopted by the EIX Board of Directors on July 19, 2001 entitled “Fair Market Value Measure for Equity-Based Awards.”

14.5 Transfer Representations and Limitations.

(A) Transfer Representations. The Holder agrees that any securities acquired by him or her hereunder are being acquired for his or her own account for investment and not with a view to or for sale in connection with any distribution thereof and that he or she understands that such securities may not be sold, transferred, pledged, hypothecated, alienated, or otherwise assigned or disposed of without either registration under the Securities Act of 1933 or compliance with the exemption provided by Rule 144 or another applicable exemption under such act.

(B) Transfer Limitations with Respect to Stock Ownership Guidelines. The Holder agrees that if he or she is an officer of EIX or one of its affiliates who is covered by EIX’s Stock Ownership Guidelines for Officers (“Ownership Guidelines”) at the time the Holder proposes to sell or otherwise transfer any securities acquired by him or her hereunder or under any prior long-term incentive award granted by the Corporation to the Holder (collectively, “Acquired Securities”), the Holder will not sell or otherwise transfer any Acquired Securities if such sale or transfer would violate the Ownership Guidelines.

14.6 Award Not Funded. The Holder will have no right or claim to any specific funds, property or assets of the Companies as to any award of LTI.

14.7 Section 409A. Notwithstanding any provision of these Terms to the contrary, if the Holder is a “specified employee” as defined in Section 409A of the Code, the Holder shall not be entitled to any payment with respect to any LTI subject to Section 409A in connection with the Holder’s Separation from Service until the earlier

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of (a) the date which is six (6) months after the Holder’s Separation From Service for any reason other than the Holder’s death, or (b) the date of the Holder’s death. Any amounts otherwise payable to the Holder following the Holder’s Separation From Service that are not so paid by reason of this Section 14.7 shall be paid as soon as practicable for EIX (and in all events within ninety (90) days) after the date that is six (6) months after the Holder’s Separation From Service (or, if earlier, the date of the Holder’s death). The provisions of this Section 14.7 shall only apply if, and to the extent, required to comply with Section 409A of the Code.

14.8 Claw-Back. Notwithstanding any provision of these Terms to the contrary, the LTI, as well as any shares of Common Stock, cash or other property that may be issued, delivered or paid in respect of the LTI, as well as any consideration that may be received in respect of a sale or other disposition of any such shares or property, shall be subject to any recoupment, “clawback” or similar provisions of applicable law, as well as any recoupment, “clawback” or similar policies of the Company that may be in effect from time to time.

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EX-31.1

Exhibit 31.1

CERTIFICATION

I, PEDRO J. PIZARRO, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, of Edison International;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2017

/s/ PEDRO J. PIZARRO

PEDRO J. PIZARRO

Chief Executive Officer

Exhibit 31.1

CERTIFICATION

I, MARIA RIGATTI, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, of Edison International;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15(d)-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2017

/s/ MARIA RIGATTI

MARIA RIGATTI

Chief Financial Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, KEVIN M. PAYNE, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, of Southern California Edison Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15(d)-15(f)) for the registrant and have:

        (a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

        (b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

        (c)   Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

        (d)   Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

        (a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

        (b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2017

/s/ KEVIN M. PAYNE

KEVIN M. PAYNE

Chief Executive Officer

Exhibit 31.2

CERTIFICATION

I, WILLIAM M. PETMECKY III, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, of Southern California Edison Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15(d)-15(f)) for the registrant and have:

        (a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

        (b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

        (c)   Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

        (d)   Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

        (a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

        (b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2017

/s/ WILLIAM M. PETMECKY III

WILLIAM M. PETMECKY III

Chief Financial Officer

EX-32.1

Exhibit 32.1

STATEMENT PURSUANT TO 18 U.S.C. SECTION 1350, AS

ENACTED BY SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q for the quarter ended March 31, 2017 (the "Quarterly Report"), of Edison International (the "Company"), and pursuant to 18 U.S.C. Section 1350, as enacted by Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned certifies, to the best of his or her knowledge, that:

1. The Quarterly Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 1, 2017

/s/ PEDRO J. PIZARRO

PEDRO J. PIZARRO

Chief Executive Officer

Edison International

/s/ MARIA RIGATTI

MARIA RIGATTI

Chief Financial Officer

Edison International

This statement accompanies the Quarterly Report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not, except to the extent required by the Sarbanes-Oxley Act of 2002, be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended.

A signed original of this written statement has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

STATEMENT PURSUANT TO 18 U.S.C. SECTION 1350, AS

ENACTED BY SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q for the quarter ended March 31, 2017 (the "Quarterly Report"), of Southern California Edison Company (the "Company"), and pursuant to 18 U.S.C. Section 1350, as enacted by Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned certifies, to the best of his knowledge, that:

1. The Quarterly Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 1, 2017

/s/ KEVIN M. PAYNE

KEVIN M. PAYNE

Chief Executive Officer

Southern California Edison Company

/s/ WILLIAM M. PETMECKY III

WILLIAM M. PETMECKY III

Chief Financial Officer

Southern California Edison Company

This statement accompanies the Quarterly Report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not, except to the extent required by the Sarbanes-Oxley Act of 2002, be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended.

A signed original of this written statement has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	Apr. 28, 2017
Entity Information [Line Items]
Entity Registrant Name	EDISON INTERNATIONAL
Entity Central Index Key	0000827052
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding		325,811,206
Southern California Edison
Entity Information [Line Items]
Entity Registrant Name	SOUTHERN CALIFORNIA EDISON CO
Entity Central Index Key	0000092103
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding		434,888,104

XML

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Total operating revenue	$ 2,463	$ 2,440
Purchased power and fuel	784	794
Operation and maintenance	596	629
Depreciation, decommissioning and amortization	499	477
Property and other taxes	100	92
Impairment and other charges	5	0
Total operating expenses	1,984	1,992
Operating income	479	448
Interest and other income	33	31
Interest expense	(152)	(140)
Other expenses	(8)	(6)
Income from continuing operations before income taxes	352	333
Income tax (benefit) expense	(40)	28
Income from continuing operations	392	305
Income from discontinued operations, net of tax	0	1
Net income	392	306
Preferred and preference stock dividend requirements of SCE	31	30
Other noncontrolling interests	(1)	(5)
Net income attributable to Edison International common shareholders	362	281
Amounts attributable to Edison International common shareholders:
Income from continuing operations, net of tax	362	280
Income from discontinued operations, net of tax	0	1
Net income attributable to Edison International common shareholders	$ 362	$ 281
Basic earnings per common share attributable to Edison International common shareholders:
Weighted average common shares outstanding (in shares)	326	326
Continuing operations (in dollars per share)	$ 1.11	$ 0.86
Total (in dollars per share)	$ 1.11	$ 0.86
Diluted earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding, including effect of dilutive securities (in shares)	329	329
Continuing operations (in dollars per share)	$ 1.10	$ 0.85
Total (in dollars per share)	1.10	0.85
Dividends declared per common share (in dollars per share)	$ 0.5425	$ 0.4800
Southern California Edison Company
Total operating revenue	$ 2,456	$ 2,435
Purchased power and fuel	784	794
Operation and maintenance	571	603
Depreciation, decommissioning and amortization	497	475
Property and other taxes	97	91
Total operating expenses	1,949	1,963
Operating income	507	472
Interest and other income	33	31
Interest expense	(141)	(131)
Other expenses	(7)	(5)
Income from continuing operations before income taxes	392	367
Income tax (benefit) expense	12	42
Net income	380	325
Preferred and preference stock dividend requirements of SCE	31	30
Net income attributable to Edison International common shareholders	349	295
Amounts attributable to Edison International common shareholders:
Net income attributable to Edison International common shareholders	$ 349	$ 295

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Net income	$ 392	$ 306
Pension and postretirement benefits other than pensions:
Amortization of net loss included in net income	2	2
Other	2	0
Other comprehensive income, net of tax	4	2
Comprehensive income	396	308
Less: Comprehensive income attributable to noncontrolling interests	30	25
Comprehensive income attributable to Edison International	366	283
Southern California Edison Company
Net income	380	325
Pension and postretirement benefits other than pensions:
Amortization of net loss included in net income	1	1
Other	1	0
Other comprehensive income, net of tax	2	1
Comprehensive income	$ 382	$ 326

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
ASSETS
Cash and cash equivalents	$ 150	$ 96
Receivables, less allowance	688	714
Accrued unbilled revenue	266	370
Inventory	237	239
Derivative assets	69	73
Regulatory assets	394	350
Other current assets	242	281
Total current assets	2,046	2,123
Nuclear decommissioning trusts	4,352	4,242
Other investments	89	83
Total investments	4,441	4,325
Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates	36,951	36,806
Nonutility property, plant and equipment, less accumulated depreciation	217	194
Total property, plant and equipment	37,168	37,000
Regulatory assets	7,674	7,455
Other long-term assets	411	416
Total long-term assets	8,085	7,871
Total assets	51,740	51,319
LIABILITIES AND EQUITY
Short-term debt	295	1,307
Current portion of long-term debt	981	981
Accounts payable	844	1,342
Accrued taxes	86	50
Customer deposits	272	269
Derivative liabilities	237	216
Regulatory liabilities	804	756
Other current liabilities	897	991
Total current liabilities	4,416	5,912
Long-term debt	11,662	10,175
Deferred income taxes and credits	8,523	8,327
Derivative liabilities	989	941
Pensions and benefits	1,358	1,354
Asset retirement obligations	2,585	2,590
Regulatory liabilities	5,910	5,726
Other deferred credits and other long-term liabilities	2,048	2,102
Total deferred credits and other liabilities	21,413	21,040
Total liabilities	37,491	37,127
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest	7	5
Common stock, no par value	2,510	2,505
Accumulated other comprehensive loss	(49)	(53)
Retained earnings	9,590	9,544
Total common shareholder's equity	12,051	11,996
Noncontrolling interests – preferred and preference stock of SCE	2,191	2,191
Total equity	14,242	14,187
Total liabilities and equity	51,740	51,319
Southern California Edison Company
ASSETS
Cash and cash equivalents	100	39
Receivables, less allowance	670	699
Accrued unbilled revenue	265	369
Inventory	235	239
Derivative assets	69	73
Regulatory assets	394	350
Other current assets	307	262
Total current assets	2,040	2,031
Nuclear decommissioning trusts	4,352	4,242
Other investments	61	50
Total investments	4,413	4,292
Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates	36,951	36,806
Nonutility property, plant and equipment, less accumulated depreciation	75	75
Total property, plant and equipment	37,026	36,881
Regulatory assets	7,674	7,455
Other long-term assets	231	232
Total long-term assets	7,905	7,687
Total assets	51,384	50,891
LIABILITIES AND EQUITY
Short-term debt	0	769
Current portion of long-term debt	579	579
Accounts payable	847	1,344
Accrued taxes	88	45
Customer deposits	272	269
Derivative liabilities	237	216
Regulatory liabilities	804	756
Other current liabilities	656	729
Total current liabilities	3,483	4,707
Long-term debt	10,843	9,754
Deferred income taxes and credits	10,323	9,886
Derivative liabilities	989	941
Pensions and benefits	898	896
Asset retirement obligations	2,580	2,586
Regulatory liabilities	5,910	5,726
Other deferred credits and other long-term liabilities	1,735	1,912
Total deferred credits and other liabilities	22,435	21,947
Total liabilities	36,761	36,408
Commitments and contingencies (Note 11)
Common stock, no par value	2,168	2,168
Additional paid-in capital	660	657
Accumulated other comprehensive loss	(18)	(20)
Retained earnings	9,568	9,433
Total common shareholder's equity	12,378	12,238
Noncontrolling interests – preferred and preference stock of SCE	2,245	2,245
Total equity	14,623	14,483
Total liabilities and equity	$ 51,384	$ 50,891

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Receivables, allowances for uncollectible accounts	$ 55	$ 62
Utility property, plant and equipment, accumulated depreciation	9,321	9,000
Nonutility property, plant and equipment, accumulated depreciation	$ 102	$ 99
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	800,000,000	800,000,000
Common stock, shares issued	325,811,206	325,811,206
Common stock, shares outstanding	325,811,206	325,811,206
Southern California Edison Company
Receivables, allowances for uncollectible accounts	$ 55	$ 61
Utility property, plant and equipment, accumulated depreciation	9,321	9,000
Nonutility property, plant and equipment, accumulated depreciation	$ 91	$ 89
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	560,000,000	560,000,000
Common stock, shares issued	434,888,104	434,888,104
Common stock, shares outstanding	434,888,104	434,888,104

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities:
Net income	$ 392	$ 306
Less: income from discontinued operations	0	1
Income from continuing operations	392	305
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	520	499
Allowance for equity during construction	(19)	(22)
Impairment and other charges	5	0
Deferred income taxes and investment tax credits	(13)	27
Other	5	5
Nuclear decommissioning trusts	1	(106)
Changes in operating assets and liabilities:
Receivables	26	117
Inventory	2	(1)
Accounts payable	(226)	(184)
Prepaid and accrued taxes	34	66
Other current assets and liabilities	50	(43)
Derivative assets and liabilities	(12)	5
Regulatory assets and liabilities	129	119
Other noncurrent assets and liabilities	(15)	68
Net cash provided by operating activities	879	855
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs	1,524	397
Long-term debt matured	(40)	(40)
Preference stock issued, net	0	294
Preference stock redeemed	0	(125)
Short-term debt financing, net	(1,013)	(332)
Settlements of stock-based compensation, net	139	51
Dividends to noncontrolling interests	(37)	(35)
Dividends paid	(177)	(156)
Other	(6)	3
Net cash provided by (used in) financing activities	112	(45)
Cash flows from investing activities:
Capital expenditures	(939)	(951)
Proceeds from sale of nuclear decommissioning trust investments	1,718	793
Purchases of nuclear decommissioning trust investments	(1,719)	(687)
Other	3	11
Net cash used in investing activities	(937)	(834)
Net increase (decrease) in cash and cash equivalents	54	(24)
Cash and cash equivalents at beginning of period	96	161
Cash and cash equivalents at end of period	150	137
Southern California Edison Company
Cash flows from operating activities:
Net income	380	325
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	517	496
Allowance for equity during construction	(19)	(22)
Deferred income taxes and investment tax credits	223	54
Other	3	3
Nuclear decommissioning trusts	1	(106)
Changes in operating assets and liabilities:
Receivables	28	100
Inventory	5	5
Accounts payable	(226)	(175)
Prepaid and accrued taxes	(33)	60
Other current assets and liabilities	71	(25)
Derivative assets and liabilities	(12)	5
Regulatory assets and liabilities	129	119
Other noncurrent assets and liabilities	(136)	45
Net cash provided by operating activities	931	884
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs	1,126	0
Long-term debt matured	(40)	(40)
Preference stock issued, net	0	294
Preference stock redeemed	0	(125)
Short-term debt financing, net	(769)	52
Dividends paid	(227)	(205)
Other	(34)	(33)
Net cash provided by (used in) financing activities	56	(57)
Cash flows from investing activities:
Capital expenditures	(929)	(950)
Proceeds from sale of nuclear decommissioning trust investments	1,718	793
Purchases of nuclear decommissioning trust investments	(1,719)	(687)
Other	4	12
Net cash used in investing activities	(926)	(832)
Net increase (decrease) in cash and cash equivalents	61	(5)
Cash and cash equivalents at beginning of period	39	26
Cash and cash equivalents at end of period	$ 100	$ 21

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Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Discounts and issuance costs of long term debt	$ 11	$ 3
Southern California Edison Company
Discounts and issuance costs of long term debt	$ 9

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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, Inc., 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 competitive 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 significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 2016 (the "2016 Form 10-K"). This quarterly report should be read in conjunction with the financial statements and notes included in the 2016 Form 10-K.

In the opinion of management, all adjustments, consisting of recurring accruals, have been made that are necessary to fairly state the consolidated financial position, results of operations, and cash flows in accordance with accounting principles generally accepted in the United States ("GAAP") for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three-month period ended March 31, 2017 are not necessarily indicative of the operating results for the full year.

The December 31, 2016 financial statement data was derived from audited financial statements, but does not include all disclosures required by GAAP.

During the fourth quarter of 2016, Edison International and SCE early adopted an accounting standard for share-based payments using the modified retrospective approach, effective January 1, 2016. Prior year financial statements have been updated to reflect the modified retrospective application of this accounting standard. For further information, see Note 1 and Note 18 of "Notes to Consolidated Financial Statements" included in the 2016 Form 10-K and Note 2 and Note 7 of this Form 10-Q.

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
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Money market funds	$	111	$	41	$	87	$	18

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
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Book balances reclassified to accounts payable	$	75	$	138	$	70	$	136

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:

	Three months ended March 31,
(in millions, except per-share amounts)	2017		2016
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Weighted average common shares outstanding	326		326
Basic earnings per share – continuing operations	$	1.11	$	0.86
Diluted earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Income impact of assumed conversions	—		—
Income from continuing operations available to common shareholders and assumed conversions	$	362	$	280
Weighted average common shares outstanding	326		326
Incremental shares from assumed conversions	3		3
Adjusted weighted average shares – diluted	329		329
Diluted earnings per share – continuing operations	$	1.10	$	0.85

In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 1,355,930 and 2,023,787 shares of common stock for the three months ended March 31, 2017 and 2016, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.

New Accounting Guidance

Accounting Guidance Not Yet Adopted

In May 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016 and 2017. 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. As of March 31, 2017, approximately 98% of total operating revenue arises from SCE's tariff offerings that provide electricity to customers. For such arrangements, revenue from contracts with customers will be equivalent to the electricity supplied and billed in that period (including estimated billings). As such, there will not be a change in the timing or pattern of revenue recognition for such sales. 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.

The FASB also issued accounting standards updates related to the impairment of financial instruments (effective January 1, 2020) and the presentation of certain cash receipts and payments in the statement of cash flows (effective January 1, 2018). Edison International and SCE are currently evaluating these updates to accounting standards.

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.

In March 2017, the FASB issued an accounting standards update which amends the current requirements related to the presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's results of operations, but will result in the separate presentation of service costs as an operating expense and non-service costs within other income and expense. Edison International and SCE are currently evaluating the impact this standard will have on the consolidated balance sheets. The new standards update is effective on January 1, 2018. It is required to be applied on a retrospective basis for the presentation of the service cost component and the other components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit cost.

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Consolidated Statements of Changes in Equity

3 Months Ended

Mar. 31, 2017

Equity [Abstract]

Consolidated Statements of Changes in Equity

Consolidated Statements of Changes in Equity

The following table provides Edison International's changes in equity for the three months ended March 31, 2017:

	Equity Attributable to Common Shareholders											Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings			Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2016	$	2,505	$	(53	)	$	9,544		$	11,996		$	2,191		$	14,187
Net income	—		—			362			362			31			393
Other comprehensive income	—		4			—			4			—			4
Common stock dividends declared ($0.5425 per share)	—		—			(177		)	(177		)	—			(177		)
Dividends to noncontrolling interests	—		—			—			—			(31		)	(31		)
Stock-based compensation	—		—			(139		)	(139		)	—			(139		)
Non-cash stock-based compensation	5		—			—			5			—			5
Balance at March 31, 2017	$	2,510	$	(49	)	$	9,590		$	12,051		$	2,191		$	14,242

The following table provides Edison International's changes in equity for the three months ended March 31, 2016:

	Equity Attributable to Common Shareholders												Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings				Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2015	$	2,484	$	(56	)	$	8,940			$	11,368		$	2,020		$	13,388
Net income	—		—			281			1	281			30			311
Other comprehensive income	—		2			—				2			—			2
Common stock dividends declared ($0.4800 per share)	—		—			(156		)		(156		)	—			(156		)
Dividends to noncontrolling interests	—		—			—				—			(30		)	(30		)
Stock-based compensation	—		—			(8		)	1	(8		)	—			(8		)
Non-cash stock-based compensation	6		—			—				6			—			6
Issuance of preference stock	—		—			—				—			294			294
Redemption of preference stock	—		—			(3		)		(3		)	(122		)	(125		)
Balance at March 31, 2016	$	2,490	$	(54	)	$	9,054			$	11,490		$	2,192		$	13,682

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 and stock-based compensation (as previously reported) were $271 million and $(50) million, respectively, for the three months ended March 31, 2016.

The following table provides SCE's changes in equity for the three months ended March 31, 2017:

	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, 2016	$	2,168	$	657	$	(20	)	$	9,433		$	2,245	$	14,483
Net income	—		—		—			380			—		380
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(191		)	—		(191		)
Dividends declared on preferred and preference stock	—		—		—			(31		)	—		(31		)
Stock-based compensation	—		—		—			(23		)	—		(23		)
Non-cash stock-based compensation	—		3		—			—			—		3
Balance at March 31, 2017	$	2,168	$	660	$	(18	)	$	9,568		$	2,245	$	14,623

The following table provides SCE's changes in equity for the three months ended March 31, 2016:

	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, 2015	$	2,168	$	652		$	(22	)	$	8,804			$	2,070		$	13,672
Net income	—		—			—			325			1	—			325
Other comprehensive income	—		—			1			—				—			1
Dividends declared on common stock	—		—			—			(170		)		—			(170		)
Dividends declared on preferred and preference stock	—		—			—			(30		)		—			(30		)
Stock-based compensation	—		—			—			(28		)	1	—			(28		)
Non-cash stock-based compensation	—		3			—			—				—			3
Issuance of preference stock	—		(6		)	—			—				300			294
Redemption of preference stock	—		3			—			(3		)		(125		)	(125		)
Balance at March 31, 2016	$	2,168	$	652		$	(21	)	$	8,898			$	2,245		$	13,942

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 and stock-based compensation (as previously reported) were $317 million and $(34) million, respectively, for the three months ended March 31, 2016.

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Variable Interest Entities

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entities

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. Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs. Commercial and operating activities include construction, operation and maintenance, fuel procurement, dispatch, and compliance with regulatory and contractual requirements.

Variable Interest in VIEs that are not Consolidated

Power Purchase Agreements

SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities 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 California Public Utilities Commission ("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 of the 2016 Form 10-K. 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 4,928 MW and 4,383 MW at March 31, 2017 and 2016, respectively, and the amounts that SCE paid to these projects were $140 million and $127 million for the three months ended March 31, 2017 and 2016, 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. 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.

The Trust I, Trust II, Trust III, Trust IV, and Trust V balance sheets as of March 31, 2017 and December 31, 2016, consisted of investments of $475 million, $400 million, $275 million, $325 million, and $300 million in the Series F, Series G, Series H, Series J, and Series K Preference Stock, respectively, $475 million, $400 million, $275 million, $325 million, and $300 million of trust securities, respectively, and $10,000 each of common stock.

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

	Three months ended March 31,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2017
Dividend income	$	7	$	5	$	4	$	4	$	4
Dividend distributions	7		5		4		4		4
2016
Dividend income	$	7	$	5	$	4	$	4	$	1
Dividend distributions	7		5		4		4		1

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Fair Value Measurements

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

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 March 31, 2017 and December 31, 2016, 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.

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 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:

	March 31, 2017
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	15	$	55		$	—	$	70
Other	103		—		—			—		103
Nuclear decommissioning trusts:
Stocks2	1,537		—		—			—		1,537
Fixed Income3	1,153		1,588		—			—		2,741
Short-term investments, primarily cash equivalents	88		84		—			—		172
Subtotal of nuclear decommissioning trusts4	2,778		1,672		—			—		4,450
Total assets	2,881		1,687		55			—		4,623
Liabilities at fair value
Derivative contracts	—		5		1,221			—		1,226
Total liabilities	—		5		1,221			—		1,226
Net assets (liabilities)	$	2,881	$	1,682	$	(1,166	)	$	—	$	3,397

	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

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 68% and 70% of SCE's equity investments were located in the United States at March 31, 2017 and December 31, 2016, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $83 million and $79 million at March 31, 2017 and December 31, 2016, respectively.

⁴  Excludes net payables of $98 million and $127 million at March 31, 2017 and December 31, 2016, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

Edison International Parent and Other

Edison International Parent and Other assets measured at fair value consisted of money market funds of $24 million and $23 million at March 31, 2017 and December 31, 2016, 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:

	Three months ended March 31,
(in millions)	2017			2016
Fair value of net liabilities at beginning of period	$	(1,089	)	$	(1,148	)
Total realized/unrealized losses:
Included in regulatory assets and liabilities1	(77		)	(65		)
Fair value of net liabilities at end of period	$	(1,166	)	$	(1,213	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	(102	)	$	(84	)

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 material transfers between any levels during 2017 and 2016.

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.

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
March 31, 2017	$	55	$	—	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, 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
Tolling
March 31, 2017	—		1,210		Option model	Volatility of gas prices	16% - 39% (25%)
						Volatility of power prices	26% - 140% (36%)
						Power prices	$18.01 - $45.28 ($30.70)
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)

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.

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:

	March 31, 2017				December 31, 2016
(in millions)	Carrying Value1		Fair Value		Carrying Value1		Fair Value
SCE	$	11,422	$	12,665	$	10,333	$	11,539
Edison International	12,643		13,894		11,156		12,368

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.

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Debt and Credit Agreements

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Debt and Credit Agreements

Debt and Credit Agreements

Long-Term Debt

In January 2017, SCE borrowed $300 million under a Term Loan Agreement due July 2018, with a variable interest rate based on the London Interbank Offered Rate plus 65 basis points (1.53% at March 31, 2017). The proceeds were used for general corporate purposes.

In January 2017, SCE reissued $135 million of 2.625% pollution-control bonds subject to mandatory remarketing in December 2023. The proceeds were used for general corporate purposes.

In March 2017, SCE issued $700 million of 4.00% first and refunding mortgage bonds due in 2047 and Edison International issued $400 million of 2.125% senior notes due in 2020. The proceeds were used to repay commercial paper borrowings and for general corporate purposes. In addition, the proceeds from SCE's bonds were used to fund SCE's capital program.

Credit Agreements and Short-Term Debt

SCE and Edison International Parent have multi-year revolving credit facilities of $2.75 billion and $1.25 billion, respectively, 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 March 31, 2017, SCE had no outstanding commercial paper. At March 31, 2017, 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, 2016, the outstanding commercial paper, net of discount, was $769 million at a weighted-average interest rate of 0.9%.

At March 31, 2017, Edison International Parent's outstanding commercial paper, net of discount, was $295 million at a weighted-average interest rate of 1.18%. At December 31, 2016, the outstanding commercial paper, net of discount, was $538 million at a weighted-average interest rate of 0.97%.

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Derivative Instruments

3 Months Ended

Mar. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

Derivative Instruments

Derivative financial instruments are used to manage exposure to commodity price risk. These risks are managed in part by entering into forward commodity transactions, including options, swaps, and futures. To mitigate credit risk from counterparties in the event of nonperformance, master netting agreements are used whenever possible and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.

Commodity Price Risk

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

Credit and Default Risk

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

Certain power 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 $19 million and $12 million as of March 31, 2017 and December 31, 2016, respectively, for which SCE has posted $12 million collateral at both March 31, 2017 and December 31, 2016 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 March 31, 2017, SCE would be required to post $8 million of additional collateral of which $2 million is related to outstanding payables that are net of collateral already posted.

Fair Value of Derivative Instruments

SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are offset against margin and cash collateral deposits. In addition, SCE has provided collateral in the form of letters of credit. Collateral requirements can vary depending upon the level of unsecured credit extended by counterparties, changes in market prices relative to contractual commitments, and other factors. See Note 4 for a discussion of fair value of derivative instruments. The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:

	March 31, 2017
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	70		$	1	$	71		$	238		$	989	$	1,227		$	1,156
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	69		$	1	$	70		$	237		$	989	$	1,226		$	1,156

	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 the 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

¹  In addition, at March 31, 2017, there is no cash collateral posted that is not offset against derivative liabilities. 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.

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 purchased power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are 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:

	Three months ended March 31,
(in millions)	2017			2016
Realized losses	$	(2	)	$	(27	)
Unrealized losses	(85		)	(64		)

Notional Volumes of Derivative Instruments

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

		Economic Hedges
Commodity	Unit of Measure	March 31, 2017	December 31, 2016
Electricity options, swaps and forwards	GWh	1,812	1,816
Natural gas options, swaps and forwards	Bcf	123	36
Congestion revenue rights	GWh	79,224	93,319
Tolling arrangements	GWh	58,153	61,093

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Income Taxes

3 Months Ended

Mar. 31, 2017

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

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
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Income from continuing operations before income taxes	$	352		$	333		$	392		$	367
Provision for income tax at federal statutory rate of 35%	124			117			137			128
Increase in income tax from:
State tax, net of federal benefit	10			6			13			9
Property-related	(113		)	(79		)	(113		)	(79		)
Change related to uncertain tax positions	(12		)	(1		)	(11		)	(1		)
Shared-based compensation1	(43		)	(10		)	(8		)	(8		)
Other	(6		)	(5		)	(6		)	(7		)
Total income tax (benefit) expense from continuing operations	$	(40	)	$	28		$	12		$	42
Effective tax rate	(11.4		)%	8.4		%	3.1		%	11.4		%

¹   Includes state taxes for Edison International and SCE of $6 million and $1 million, respectively, for the three months ended March 31, 2017 and $3 million and $2 million, respectively, for the three months ended March 31, 2016. 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.

In March 2017, SCE received the final decision on claims against, and counterclaims of, Mitsubishi Heavy Industries, Inc. and related companies (together, "MHI") from the arbitration tribunal, the International Chamber of Commerce, discussed further in Note 11. San Onofre was permanently shut down on June 7, 2013 as a result of failure of replacement steam generators supplied by MHI. With the resolution of the insurance claim against Nuclear Electric Insurance Limited ("NEIL") in October 2015 and the conclusion of the arbitration proceeding against MHI, a tax abandonment loss of $698 million and $1.14 billion for federal and state income tax purposes, respectively, was claimed in the first quarter of 2017, resulting in a flow-through tax benefit of approximately $39 million impacting the effective tax rate. Due to the tax abandonment loss recognized this quarter, Edison International and SCE both expect to report a federal taxable loss in 2017. In addition, Edison International expects to report a California taxable loss in 2017. 

Unrecognized Tax Benefits

In the first quarter of 2017, Edison International settled all open tax positions with the Internal Revenue Service ("IRS") for taxable years 2007 through 2012. The following table provides a reconciliation of unrecognized tax benefits for 2017 as a result of the audit settlement:

(in millions)	Edison International			SCE
Balance at January 1, 2017	$	471		$	371
Tax positions taken during the current year:
Increases	10			10
Tax positions taken during a prior year:
Increases	2			2
Decreases	(10		)	(10		)
Decreases for settlements during the period	(82		)	(78		)
Balance at March 31, 2017	$	391		$	295

Tax Disputes

Tax Years 2007 – 2012

In the first quarter of 2017, Edison International settled all open tax positions with the IRS for taxable years 2007 through 2012. Edison International previously made cash deposits which are sufficient to settle all outstanding liabilities for this audit cycle. Total liabilities included tax reserves, previously settled issues, and an estimate of associated interest and penalties. 

Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2013 – 2015 and 2010 – 2015, respectively. Edison International has settled all open tax position with the IRS for taxable years prior to 2013.  Tax years 2003 – 2009 are currently under protest with the California Franchise Tax Board.

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Compensation and Benefit Plans

3 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [Abstract]

Compensation and Benefit Plans

Compensation and Benefit Plans

Pension Plans

Edison International made contributions of $25 million during the three months ended March 31, 2017, which includes contributions of $21 million by SCE. Edison International expects to make contributions of $111 million during the remainder of 2017, which includes $64 million from SCE. Annual contributions made by SCE to most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms.

Pension expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	36		$	39		$	35		$	38
Interest cost	41			44			37			41
Expected return on plan assets	(53		)	(56		)	(50		)	(53		)
Amortization of prior service cost	1			1			1			1
Amortization of net loss1	5			9			4			8
Expense under accounting standards	$	30		$	37		$	27		$	35
Regulatory adjustment	(3		)	(9		)	(3		)	(9		)
Total expense recognized	$	27		$	28		$	24		$	26

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $2 million, respectively, for the three months ended March 31, 2017, and $3 million and $2 million, respectively, for the three months ended March 31, 2016.

Under GAAP, a settlement is recorded when lump-sum payments exceed estimated annual service and interest costs. Lump sum payments made in April 2017 to Edison International executives retiring in 2016 from the Executive Retirement Plan exceeded the estimated service and interest costs, resulting in a partial settlement of that plan. A settlement loss of approximately $7.7 million ($4.6 million after-tax) is expected to be recorded at Edison International in the second quarter of 2017.

Postretirement Benefits Other Than Pensions

Edison International made contributions of $5 million during the three months ended March 31, 2017 and expects to make contributions of $16 million during the remainder of 2017, substantially all of which are expected to be made by SCE. 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. Benefits under these plans, with some exceptions, are generally unvested and subject to change. Under the terms of the Edison International Health and Welfare Plan ("PBOP Plan") each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of all PBOP Plan benefits with respect to its employees and former employees. A participating employer may terminate the PBOP Plan benefits with respect to its employees and former employees, as may SCE (as PBOP Plan sponsor), and, accordingly, the participants' PBOP Plan benefits are not vested benefits.

PBOP expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	9		$	10		$	9		$	10
Interest cost	24			26			24			26
Expected return on plan assets	(27		)	(28		)	(27		)	(28		)
Amortization of prior service cost	(1		)	(1		)	(1		)	(1		)
Total expense	$	5		$	7		$	5		$	7

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Investments

3 Months Ended

Mar. 31, 2017

Regulated Entity, Other Assets, Noncurrent [Abstract]

Investments

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 Dates	Amortized Cost				Fair Value
(in millions)		March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Stocks	—	$	291	$	319	$	1,537	$	1,547
Municipal bonds	2054	645		659		753		766
U.S. government and agency securities	2055	1,308		1,131		1,380		1,191
Corporate bonds	2057	552		600		608		659
Short-term investments and receivables/payables1	One-year	71		75		74		79
Total		$	2,867	$	2,784	$	4,352	$	4,242

¹ Short-term investments include $36 million and $114 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by April 3, 2017 and January 4, 2017 as of March 31, 2017 and December 31, 2016, respectively.

Trust fund earnings (based on specific identification) increase the trust fund balance and the asset retirement obligation ("ARO") regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion at both March 31, 2017 and December 31, 2016.

The following table sets forth a summary of changes in the fair value of the trust:

	Three months ended March 31,
(in millions)	2017			2016
Balance at beginning of period	$	4,242		$	4,331
Gross realized gains	99			17
Gross realized losses	(16		)	(3		)
Unrealized gains, net of losses	27			59
Other-than-temporary impairments	(1		)	(7		)
Interest and dividends	28			29
Income taxes	—			(18		)
Decommissioning disbursements	(26		)	(116		)
Administrative expenses and other	(1		)	(2		)
Balance at end of period	$	4,352		$	4,290

Trust assets are used to pay income taxes. Deferred tax liabilities related to net unrealized gains at March 31, 2017 were $373 million. Accordingly, the fair value of trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $4.0 billion at March 31, 2017. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.

Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts.

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Regulatory Assets and Liabilities

3 Months Ended

Mar. 31, 2017

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

Regulatory Assets

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	139	$	135
Energy derivatives	186		150
Unamortized investments, net of accumulated amortization	37		49
Other	32		16
Total current	394		350
Long-term:
Deferred income taxes, net of liabilities	4,689		4,478
Pensions and other postretirement benefits	711		710
Energy derivatives	996		947
Unamortized investments, net of accumulated amortization	79		80
San Onofre	815		857
Unamortized loss on reacquired debt	180		184
Regulatory balancing accounts	68		66
Environmental remediation	125		126
Other	11		7
Total long-term	7,674		7,455
Total regulatory assets	$	8,068	$	7,805

Regulatory Liabilities

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	740	$	736
San Onofre MHI arbitration award1	47		—
Other	17		20
Total current	804		756
Long-term:
Costs of removal	2,838		2,847
Recoveries in excess of ARO liabilities2	1,735		1,639
Regulatory balancing accounts	1,278		1,180
Other	59		60
Total long-term	5,910		5,726
Total regulatory liabilities	$	6,714	$	6,482

¹ Represents SCE's net recovery from claims against MHI. See Note 11 for further discussion.

² Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9 for further discussion.

Net Regulatory Balancing Accounts

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

(in millions)	March 31, 2017			December 31, 2016
Asset (liability)
Energy resource recovery account	$	30		$	(20	)
New system generation balancing account	(97		)	(6		)
Public purpose programs and energy efficiency programs	(1,056		)	(992		)
Tax accounting memorandum account and pole loading balancing account	(136		)	(142		)
Base rate recovery balancing account	(360		)	(426		)
Department of Energy litigation memorandum account	(123		)	(122		)
Greenhouse gas auction revenue	(3		)	31
FERC balancing accounts	(93		)	(69		)
Other	27			31
Liability	$	(1,811	)	$	(1,715	)

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Third-Party Power Purchase Agreements

During the first quarter of 2017, SCE had existing PPAs that met the critical contract provisions. The commitments for these contracts are estimated to be: $48 million in 2017, $116 million in 2018, $117 million in 2019, $119 million in 2020, $120 million in 2021, and $955 million for the remaining period thereafter. For further information, see Note 11 in the 2016 Form 10-K.

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 the Mountainview power plant'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 Settlement Agreement by and among SCE, The Utility Reform Network, the CPUC's Office of Ratepayer Advocates and San Diego Gas & Electric ("SDG&E"), which was later joined by the Coalition of California Utility Employees and Friends of the Earth, dated November 20, 2014 (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 Order Instituting Investigation ("OII") proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned administrative law judge ("ALJ") to consider whether, in light of SCE 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 San Onofre OII Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the San Onofre 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 San Onofre 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 and SDG&E to meet and confer with the other parties in the San Onofre 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. The parties held three meet-and-confer sessions. In March 2017, SCE and other parties reported to the CPUC that the parties participating in the meet-and-confer process have agreed to mediate the issues identified in the December 2016 joint ruling. In April 2017, SCE and other meet-and-confer parties filed a joint motion to extend the April 28, 2017 joint report deadline to August 15, 2017. SCE has recorded a regulatory asset of $815 million at March 31, 2017 to reflect the expected recoveries under the San Onofre OII Settlement Agreement. Management assesses at the end of each reporting period whether regulatory assets are probable of future recovery. SCE assessed the San Onofre regulatory asset at March 31, 2017 and continues to conclude that the asset is

probable, though not certain, of recovery based on SCE's knowledge of facts and judgment in applying the relevant regulatory principles to the issue. SCE does not believe that the conclusions in the MHI arbitration, discussed below, change the expectation on the probability of recovery of the San Onofre regulatory asset.

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. In light of the San Onofre OII meet-and-confer sessions, the Ninth Circuit cancelled the hearing 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 federal 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 and a decision is pending.

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 federal court granted defendants' motion to dismiss the consolidated complaint, with an opportunity for plaintiffs to amend the complaint. Plaintiffs did not file an amended complaint by the required date. Plaintiffs' deadline to appeal the federal court's order granting defendants' motion to dismiss lapsed in March 2017 and no appeal was filed.

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. 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. These defendants' motion was heard by the court in November 2016 and a decision is pending.

Edison International and SCE cannot predict the outcome of the open proceedings.

MHI Claims

SCE pursued claims against MHI, which designed and supplied the replacement steam generators. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce seeking damages for all losses. SCE alleged contract and tort claims and sought at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI denied any liability and asserted counterclaims for $41 million, for which SCE denied any liability. Each of the other San Onofre owners (SDG&E and Riverside) 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 were added as additional claimants in the arbitration. In March 2017, the arbitration

tribunal found MHI liable for breach of contract, but rejected claimants' other claims. The tribunal found that damages were subject to contractual limitations on liability. In addition, the tribunal ordered the claimants to pay MHI's legal costs but rejected MHI's counterclaims. The net recovery awarded to SCE was initially determined to be $52 million. An adjustment to the interest awarded to SCE subsequently reduced the net recovery to approximately $47 million. The decision is the final award of the tribunal but can be challenged in court on limited grounds. SCE has determined that it will not appeal the decision. As a result of uncertainty associated with the allocation of the award under the San Onofre OII Settlement Agreement, SCE recorded a regulatory liability for the net recovery.

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 March 31, 2017, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites with a liability balance at March 31, 2017, in which the upper end of the range of the costs is at least $1 million) was $127 million, including $75 million related to San Onofre. In addition to these sites, SCE also has 17 immaterial sites with a liability balance as of March 31, 2017, for which the total minimum recorded liability was $3 million. Of the $130 million total environmental remediation liability for SCE, $125 million has been recorded as a regulatory asset. SCE expects to recover $47 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $78 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.

The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $149 million and $8 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.

SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next five years are expected to range from $5 million to $18 million. Costs incurred for the three months ended March 31, 2017 and 2016 were $2 million and $1 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

SCE is a member of NEIL, a mutual insurance company owned by entities with nuclear facilities. NEIL provides insurance for nuclear property damage, including damages caused by acts of terrorism up to specified limits, and for accidental outages for active facilities. The amount of nuclear property damage insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $1.06 billion. If NEIL losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $52 million per year.

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. 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.

For more information on nuclear insurance coverage, see Note 11 in the 2016 Form 10-K.

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 U.S. Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. 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 accepted the DOE's determination, and the government will pay the 2014 – 2015 claim under the terms of the settlement. 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.

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Accumulated Other Comprehensive Loss

3 Months Ended

Mar. 31, 2017

Equity [Abstract]

Accumulated Other Comprehensive Loss

Accumulated Other Comprehensive Loss

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

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Beginning balance	$	(53	)	$	(56	)	$	(20	)	$	(22	)
Pension and PBOP – net loss:
Reclassified from accumulated other comprehensive loss1	2			2			1			1
Other	2			—			1			—
Change	4			2			2			1
Ending Balance	$	(49	)	$	(54	)	$	(18	)	$	(21	)

¹  These items are included in the computation of net periodic pension and PBOP Plan expense. See Note 8 for additional information.

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Interest and Other Income and Other Expenses

3 Months Ended

Mar. 31, 2017

Other Income and Expenses [Abstract]

Interest and Other Income and Other Expenses

Interest and Other Income and Other Expenses

Interest and other income and other expenses are as follows:

	Three months ended March 31,
(in millions)	2017			2016
SCE interest and other income:
Equity allowance for funds used during construction	$	19		$	22
Increase in cash surrender value of life insurance policies and life insurance benefits	12			7
Interest income	1			—
Other	1			2
Total SCE interest and other income	33			31
Total Edison International interest and other income	$	33		$	31
SCE other expenses:
Civic, political and related activities and donations	$	(4	)	$	(5	)
Other	(3		)	—
Total SCE other expenses	(7		)	(5		)
Other expenses of Edison International Parent and Other	(1		)	(1		)
Total Edison International other expenses	$	(8	)	$	(6	)

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Supplemental Cash Flows Information

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flows Information

Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International				SCE
	Three months ended March 31,
(in millions)	2017		2016		2017		2016
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	167	$	158	$	152	$	149
Tax payments, net of refunds	—		2		—		11
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	177	$	156	$	—	$	—
Preferred and preference stock	1		1		1		1

SCE's accrued capital expenditures at March 31, 2017 and 2016 were $275 million and $360 million, respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid.

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Organization and Basis of Presentation

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, Inc., 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 competitive 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 significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 2016 (the "2016 Form 10-K"). This quarterly report should be read in conjunction with the financial statements and notes included in the 2016 Form 10-K.

In the opinion of management, all adjustments, consisting of recurring accruals, have been made that are necessary to fairly state the consolidated financial position, results of operations, and cash flows in accordance with accounting principles generally accepted in the United States ("GAAP") for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three-month period ended March 31, 2017 are not necessarily indicative of the operating results for the full year.

The December 31, 2016 financial statement data was derived from audited financial statements, but does not include all disclosures required by GAAP.

Cash Equivalents

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.

Earnings Per Share

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.

New Accounting Guidance

New Accounting Guidance

Accounting Guidance Not Yet Adopted

In May 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016 and 2017. 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. As of March 31, 2017, approximately 98% of total operating revenue arises from SCE's tariff offerings that provide electricity to customers. For such arrangements, revenue from contracts with customers will be equivalent to the electricity supplied and billed in that period (including estimated billings). As such, there will not be a change in the timing or pattern of revenue recognition for such sales. 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.

The FASB also issued accounting standards updates related to the impairment of financial instruments (effective January 1, 2020) and the presentation of certain cash receipts and payments in the statement of cash flows (effective January 1, 2018). Edison International and SCE are currently evaluating these updates to accounting standards.

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.

In March 2017, the FASB issued an accounting standards update which amends the current requirements related to the presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's results of operations, but will result in the separate presentation of service costs as an operating expense and non-service costs within other income and expense. Edison International and SCE are currently evaluating the impact this standard will have on the consolidated balance sheets. The new standards update is effective on January 1, 2018. It is required to be applied on a retrospective basis for the presentation of the service cost component and the other components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit cost.

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Cash Equivalents

The cash equivalents were as follows:

	Edison International				SCE
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Money market funds	$	111	$	41	$	87	$	18

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
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Book balances reclassified to accounts payable	$	75	$	138	$	70	$	136

EPS Attributable to Edison International Common Shareholders

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

	Three months ended March 31,
(in millions, except per-share amounts)	2017		2016
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Weighted average common shares outstanding	326		326
Basic earnings per share – continuing operations	$	1.11	$	0.86
Diluted earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	362	$	280
Participating securities dividends	—		—
Income from continuing operations available to common shareholders	$	362	$	280
Income impact of assumed conversions	—		—
Income from continuing operations available to common shareholders and assumed conversions	$	362	$	280
Weighted average common shares outstanding	326		326
Incremental shares from assumed conversions	3		3
Adjusted weighted average shares – diluted	329		329
Diluted earnings per share – continuing operations	$	1.10	$	0.85

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Consolidated Statements of Changes in Equity (Tables)

3 Months Ended

Mar. 31, 2017

Schedule of Capitalization, Equity [Line Items]

Schedule of Changes in Equity

The following table provides Edison International's changes in equity for the three months ended March 31, 2017:

	Equity Attributable to Common Shareholders											Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings			Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2016	$	2,505	$	(53	)	$	9,544		$	11,996		$	2,191		$	14,187
Net income	—		—			362			362			31			393
Other comprehensive income	—		4			—			4			—			4
Common stock dividends declared ($0.5425 per share)	—		—			(177		)	(177		)	—			(177		)
Dividends to noncontrolling interests	—		—			—			—			(31		)	(31		)
Stock-based compensation	—		—			(139		)	(139		)	—			(139		)
Non-cash stock-based compensation	5		—			—			5			—			5
Balance at March 31, 2017	$	2,510	$	(49	)	$	9,590		$	12,051		$	2,191		$	14,242

The following table provides Edison International's changes in equity for the three months ended March 31, 2016:

	Equity Attributable to Common Shareholders												Noncontrolling Interests
(in millions, except per-share amounts)	Common Stock		Accumulated Other Comprehensive Loss			Retained Earnings				Subtotal			Preferred and Preference Stock			Total Equity
Balance at December 31, 2015	$	2,484	$	(56	)	$	8,940			$	11,368		$	2,020		$	13,388
Net income	—		—			281			1	281			30			311
Other comprehensive income	—		2			—				2			—			2
Common stock dividends declared ($0.4800 per share)	—		—			(156		)		(156		)	—			(156		)
Dividends to noncontrolling interests	—		—			—				—			(30		)	(30		)
Stock-based compensation	—		—			(8		)	1	(8		)	—			(8		)
Non-cash stock-based compensation	6		—			—				6			—			6
Issuance of preference stock	—		—			—				—			294			294
Redemption of preference stock	—		—			(3		)		(3		)	(122		)	(125		)
Balance at March 31, 2016	$	2,490	$	(54	)	$	9,054			$	11,490		$	2,192		$	13,682

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 and stock-based compensation (as previously reported) were $271 million and $(50) million, respectively, for the three months ended March 31, 2016.

Southern California Edison

Schedule of Capitalization, Equity [Line Items]

Schedule of Changes in Equity

The following table provides SCE's changes in equity for the three months ended March 31, 2017:

	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, 2016	$	2,168	$	657	$	(20	)	$	9,433		$	2,245	$	14,483
Net income	—		—		—			380			—		380
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(191		)	—		(191		)
Dividends declared on preferred and preference stock	—		—		—			(31		)	—		(31		)
Stock-based compensation	—		—		—			(23		)	—		(23		)
Non-cash stock-based compensation	—		3		—			—			—		3
Balance at March 31, 2017	$	2,168	$	660	$	(18	)	$	9,568		$	2,245	$	14,623

The following table provides SCE's changes in equity for the three months ended March 31, 2016:

	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, 2015	$	2,168	$	652		$	(22	)	$	8,804			$	2,070		$	13,672
Net income	—		—			—			325			1	—			325
Other comprehensive income	—		—			1			—				—			1
Dividends declared on common stock	—		—			—			(170		)		—			(170		)
Dividends declared on preferred and preference stock	—		—			—			(30		)		—			(30		)
Stock-based compensation	—		—			—			(28		)	1	—			(28		)
Non-cash stock-based compensation	—		3			—			—				—			3
Issuance of preference stock	—		(6		)	—			—				300			294
Redemption of preference stock	—		3			—			(3		)		(125		)	(125		)
Balance at March 31, 2016	$	2,168	$	652		$	(21	)	$	8,898			$	2,245		$	13,942

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 and stock-based compensation (as previously reported) were $317 million and $(34) million, respectively, for the three months ended March 31, 2016.

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2017

Southern California Edison

Variable Interest Entity

Summary of Trusts' Income Statements

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

	Three months ended March 31,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2017
Dividend income	$	7	$	5	$	4	$	4	$	4
Dividend distributions	7		5		4		4		4
2016
Dividend income	$	7	$	5	$	4	$	4	$	1
Dividend distributions	7		5		4		4		1

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2017

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Carrying Amounts and Fair Values of Long-term Debt, Including Current Portion

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:

	March 31, 2017				December 31, 2016
(in millions)	Carrying Value1		Fair Value		Carrying Value1		Fair Value
SCE	$	11,422	$	12,665	$	10,333	$	11,539
Edison International	12,643		13,894		11,156		12,368

¹   Carrying value is net of debt issuance costs.

Southern California Edison

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value by Level

The following table sets forth assets and liabilities of SCE that were accounted for at fair value by level within the fair value hierarchy:

	March 31, 2017
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	15	$	55		$	—	$	70
Other	103		—		—			—		103
Nuclear decommissioning trusts:
Stocks2	1,537		—		—			—		1,537
Fixed Income3	1,153		1,588		—			—		2,741
Short-term investments, primarily cash equivalents	88		84		—			—		172
Subtotal of nuclear decommissioning trusts4	2,778		1,672		—			—		4,450
Total assets	2,881		1,687		55			—		4,623
Liabilities at fair value
Derivative contracts	—		5		1,221			—		1,226
Total liabilities	—		5		1,221			—		1,226
Net assets (liabilities)	$	2,881	$	1,682	$	(1,166	)	$	—	$	3,397

	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

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 68% and 70% of SCE's equity investments were located in the United States at March 31, 2017 and December 31, 2016, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $83 million and $79 million at March 31, 2017 and December 31, 2016, respectively.

⁴  Excludes net payables of $98 million and $127 million at March 31, 2017 and December 31, 2016, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

Summary of Changes in Fair Value of Level 3 Net Derivative Assets and Liabilities

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

	Three months ended March 31,
(in millions)	2017			2016
Fair value of net liabilities at beginning of period	$	(1,089	)	$	(1,148	)
Total realized/unrealized losses:
Included in regulatory assets and liabilities1	(77		)	(65		)
Fair value of net liabilities at end of period	$	(1,166	)	$	(1,213	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	(102	)	$	(84	)

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

Valuation Techniques and Significant Unobservable Inputs Used to Determine Fair Value for Level 3 Assets and Liabilities

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
March 31, 2017	$	55	$	—	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, 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
Tolling
March 31, 2017	—		1,210		Option model	Volatility of gas prices	16% - 39% (25%)
						Volatility of power prices	26% - 140% (36%)
						Power prices	$18.01 - $45.28 ($30.70)
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)

¹  Prices are in dollars per megawatt-hour.

²  Prices are in dollars per million British thermal units.

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2017

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Liabilities Instruments

The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:

	March 31, 2017
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	70		$	1	$	71		$	238		$	989	$	1,227		$	1,156
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	69		$	1	$	70		$	237		$	989	$	1,226		$	1,156

	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 the 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

¹  In addition, at March 31, 2017, there is no cash collateral posted that is not offset against derivative liabilities. 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.

Southern California Edison

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Asset Instruments

The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:

	March 31, 2017
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	70		$	1	$	71		$	238		$	989	$	1,227		$	1,156
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	69		$	1	$	70		$	237		$	989	$	1,226		$	1,156

	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 the 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

¹  In addition, at March 31, 2017, there is no cash collateral posted that is not offset against derivative liabilities. 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.

Summarization of Economic Hedging Activities

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

	Three months ended March 31,
(in millions)	2017			2016
Realized losses	$	(2	)	$	(27	)
Unrealized losses	(85		)	(64		)

Notional Volumes of Derivative Instruments

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

		Economic Hedges
Commodity	Unit of Measure	March 31, 2017	December 31, 2016
Electricity options, swaps and forwards	GWh	1,812	1,816
Natural gas options, swaps and forwards	Bcf	123	36
Congestion revenue rights	GWh	79,224	93,319
Tolling arrangements	GWh	58,153	61,093

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2017

Income Tax Disclosure [Abstract]

Reconciliation of Income Tax Expense

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
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Income from continuing operations before income taxes	$	352		$	333		$	392		$	367
Provision for income tax at federal statutory rate of 35%	124			117			137			128
Increase in income tax from:
State tax, net of federal benefit	10			6			13			9
Property-related	(113		)	(79		)	(113		)	(79		)
Change related to uncertain tax positions	(12		)	(1		)	(11		)	(1		)
Shared-based compensation1	(43		)	(10		)	(8		)	(8		)
Other	(6		)	(5		)	(6		)	(7		)
Total income tax (benefit) expense from continuing operations	$	(40	)	$	28		$	12		$	42
Effective tax rate	(11.4		)%	8.4		%	3.1		%	11.4		%

¹   Includes state taxes for Edison International and SCE of $6 million and $1 million, respectively, for the three months ended March 31, 2017 and $3 million and $2 million, respectively, for the three months ended March 31, 2016. Refer to Note 1 for further information.

Reconciliation of Unrecognized Tax Benefits

 The following table provides a reconciliation of unrecognized tax benefits for 2017 as a result of the audit settlement:

(in millions)	Edison International			SCE
Balance at January 1, 2017	$	471		$	371
Tax positions taken during the current year:
Increases	10			10
Tax positions taken during a prior year:
Increases	2			2
Decreases	(10		)	(10		)
Decreases for settlements during the period	(82		)	(78		)
Balance at March 31, 2017	$	391		$	295

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Compensation and Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2017

Pension Plans

Pension and Other Postretirement Benefits

Expense Components for Plans

Pension expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	36		$	39		$	35		$	38
Interest cost	41			44			37			41
Expected return on plan assets	(53		)	(56		)	(50		)	(53		)
Amortization of prior service cost	1			1			1			1
Amortization of net loss1	5			9			4			8
Expense under accounting standards	$	30		$	37		$	27		$	35
Regulatory adjustment	(3		)	(9		)	(3		)	(9		)
Total expense recognized	$	27		$	28		$	24		$	26

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $2 million, respectively, for the three months ended March 31, 2017, and $3 million and $2 million, respectively, for the three months ended March 31, 2016.

PBOP Plan

Pension and Other Postretirement Benefits

Expense Components for Plans

PBOP expense components for continuing operations are:

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Service cost	$	9		$	10		$	9		$	10
Interest cost	24			26			24			26
Expected return on plan assets	(27		)	(28		)	(27		)	(28		)
Amortization of prior service cost	(1		)	(1		)	(1		)	(1		)
Total expense	$	5		$	7		$	5		$	7

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Investments (Tables) - Southern California Edison

3 Months Ended

Mar. 31, 2017

Investment [Line Items]

Amortized Cost and Fair Value of the Trust Investments

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 Dates	Amortized Cost				Fair Value
(in millions)		March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Stocks	—	$	291	$	319	$	1,537	$	1,547
Municipal bonds	2054	645		659		753		766
U.S. government and agency securities	2055	1,308		1,131		1,380		1,191
Corporate bonds	2057	552		600		608		659
Short-term investments and receivables/payables1	One-year	71		75		74		79
Total		$	2,867	$	2,784	$	4,352	$	4,242

¹ Short-term investments include $36 million and $114 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by April 3, 2017 and January 4, 2017 as of March 31, 2017 and December 31, 2016, respectively.

Summary of Changes in the Fair Value of Trust

The following table sets forth a summary of changes in the fair value of the trust:

	Three months ended March 31,
(in millions)	2017			2016
Balance at beginning of period	$	4,242		$	4,331
Gross realized gains	99			17
Gross realized losses	(16		)	(3		)
Unrealized gains, net of losses	27			59
Other-than-temporary impairments	(1		)	(7		)
Interest and dividends	28			29
Income taxes	—			(18		)
Decommissioning disbursements	(26		)	(116		)
Administrative expenses and other	(1		)	(2		)
Balance at end of period	$	4,352		$	4,290

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Regulatory Assets and Liabilities (Tables) - Southern California Edison

3 Months Ended

Mar. 31, 2017

Regulatory Assets [Line Items]

Regulatory Assets Included on the Consolidated Balance Sheets

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	139	$	135
Energy derivatives	186		150
Unamortized investments, net of accumulated amortization	37		49
Other	32		16
Total current	394		350
Long-term:
Deferred income taxes, net of liabilities	4,689		4,478
Pensions and other postretirement benefits	711		710
Energy derivatives	996		947
Unamortized investments, net of accumulated amortization	79		80
San Onofre	815		857
Unamortized loss on reacquired debt	180		184
Regulatory balancing accounts	68		66
Environmental remediation	125		126
Other	11		7
Total long-term	7,674		7,455
Total regulatory assets	$	8,068	$	7,805

Regulatory Liabilities Included on the Consolidated Balance Sheets

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

(in millions)	March 31, 2017		December 31, 2016
Current:
Regulatory balancing accounts	$	740	$	736
San Onofre MHI arbitration award1	47		—
Other	17		20
Total current	804		756
Long-term:
Costs of removal	2,838		2,847
Recoveries in excess of ARO liabilities2	1,735		1,639
Regulatory balancing accounts	1,278		1,180
Other	59		60
Total long-term	5,910		5,726
Total regulatory liabilities	$	6,714	$	6,482

¹ Represents SCE's net recovery from claims against MHI. See Note 11 for further discussion.

² Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9 for further discussion.

Schedule of Net Regulatory Balancing Accounts

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

(in millions)	March 31, 2017			December 31, 2016
Asset (liability)
Energy resource recovery account	$	30		$	(20	)
New system generation balancing account	(97		)	(6		)
Public purpose programs and energy efficiency programs	(1,056		)	(992		)
Tax accounting memorandum account and pole loading balancing account	(136		)	(142		)
Base rate recovery balancing account	(360		)	(426		)
Department of Energy litigation memorandum account	(123		)	(122		)
Greenhouse gas auction revenue	(3		)	31
FERC balancing accounts	(93		)	(69		)
Other	27			31
Liability	$	(1,811	)	$	(1,715	)

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Accumulated Other Comprehensive Loss (Tables)

3 Months Ended

Mar. 31, 2017

Equity [Abstract]

Components of Accumulated Other Comprehensive Loss

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

	Edison International						SCE
	Three months ended March 31,
(in millions)	2017			2016			2017			2016
Beginning balance	$	(53	)	$	(56	)	$	(20	)	$	(22	)
Pension and PBOP – net loss:
Reclassified from accumulated other comprehensive loss1	2			2			1			1
Other	2			—			1			—
Change	4			2			2			1
Ending Balance	$	(49	)	$	(54	)	$	(18	)	$	(21	)

¹  These items are included in the computation of net periodic pension and PBOP Plan expense. See Note 8 for additional information.

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Interest and Other Income and Other Expenses (Tables)

3 Months Ended

Mar. 31, 2017

Other Income and Expenses [Abstract]

Interest and Other Income and Expenses

Interest and other income and other expenses are as follows:

	Three months ended March 31,
(in millions)	2017			2016
SCE interest and other income:
Equity allowance for funds used during construction	$	19		$	22
Increase in cash surrender value of life insurance policies and life insurance benefits	12			7
Interest income	1			—
Other	1			2
Total SCE interest and other income	33			31
Total Edison International interest and other income	$	33		$	31
SCE other expenses:
Civic, political and related activities and donations	$	(4	)	$	(5	)
Other	(3		)	—
Total SCE other expenses	(7		)	(5		)
Other expenses of Edison International Parent and Other	(1		)	(1		)
Total Edison International other expenses	$	(8	)	$	(6	)

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Supplemental Cash Flows Information (Tables)

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International				SCE
	Three months ended March 31,
(in millions)	2017		2016		2017		2016
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	167	$	158	$	152	$	149
Tax payments, net of refunds	—		2		—		11
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	177	$	156	$	—	$	—
Preferred and preference stock	1		1		1		1

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Summary of Significant Accounting Policies (Organization and Basis of Presentation) (Details) mi² in Thousands	3 Months Ended
	Mar. 31, 2017 mi²
Southern California Edison | Electric Utility
Segment Reporting Information [Line Items]
Supply of electricity, area covered (square mile)	50

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Summary of Significant Accounting Policies (Cash Equivalents) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Cash and Cash Equivalents Items [Line Items]
Money market funds	$ 111	$ 41
Book balances reclassified to accounts payable	75	138
Southern California Edison
Cash and Cash Equivalents Items [Line Items]
Money market funds	87	18
Book balances reclassified to accounts payable	$ 70	$ 136

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Summary of Significant Accounting Policies (Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$ 362	$ 280
Participating securities dividends	0	0
Income from continuing operations available to common shareholders	$ 362	$ 280
Weighted average common shares outstanding (in shares)	326,000,000	326,000,000
Basic earnings per share - continuing operations (in dollars per share)	$ 1.11	$ 0.86
Diluted earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$ 362	$ 280
Participating securities dividends	0	0
Income from continuing operations available to common shareholders	362	280
Income impact of assumed conversions	0	0
Income from continuing operations available to common shareholders and assumed conversions	$ 362	$ 280
Weighted average common shares outstanding (in shares)	326,000,000	326,000,000
Incremental shares from assumed conversions (in shares)	3,000,000	3,000,000
Adjusted weighted average shares - diluted (in shares)	329,000,000	329,000,000
Diluted earnings per share - continuing operations (in dollars per share)	$ 1.10	$ 0.85
Stock option awards
Diluted earnings per share – continuing operations:
Stock-based compensation awards excluded from the computation of diluted earnings per share (in shares)	1,355,930	2,023,787

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Summary of Significant Accounting Policies (New Accounting Guidance) (Details)	3 Months Ended
	Mar. 31, 2017
Southern California Edison | Sales
Concentration Risk [Line Items]
Sales from tariff offerings, percentage of total operating revenues	98.00%

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Consolidated Statements of Changes in Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	$ 14,187	$ 13,388
Net income	393	311
Net income	392	306
Other comprehensive income (loss)	4	2
Dividends declared on common stock	(177)	(156)
Dividends to noncontrolling interests	(31)	(30)
Stock-based compensation	(139)	(8)
Non-cash stock-based compensation	5	6
Issuance of preference stock		294
Redemption of preference stock		(125)
Balance, at the end of the period	$ 14,242	$ 13,682
Dividends declared per common share (in dollars per share)	$ 0.5425	$ 0.4800
Accounting for Share-Based Payments
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		$ 271
Stock-based compensation		(50)
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	$ 2,505	2,484
Non-cash stock-based compensation	5	6
Balance, at the end of the period	2,510	2,490
Accumulated Other Comprehensive Loss
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	(53)	(56)
Other comprehensive income (loss)	4	2
Balance, at the end of the period	(49)	(54)
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	9,544	8,940
Net income	362	281
Dividends declared on common stock	(177)	(156)
Stock-based compensation	(139)	(8)
Redemption of preference stock		(3)
Balance, at the end of the period	9,590	9,054
Subtotal
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	11,996	11,368
Net income	362	281
Other comprehensive income (loss)	4	2
Dividends declared on common stock	(177)	(156)
Stock-based compensation	(139)	(8)
Non-cash stock-based compensation	5	6
Redemption of preference stock		(3)
Balance, at the end of the period	12,051	11,490
Preferred and Preference Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	2,191	2,020
Net income	31	30
Dividends to noncontrolling interests	(31)	(30)
Issuance of preference stock		294
Redemption of preference stock		(122)
Balance, at the end of the period	2,191	2,192
Southern California Edison
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	14,483	13,672
Net income	380	325
Other comprehensive income (loss)	2	1
Dividends declared on common stock	(191)	(170)
Dividends declared on preferred and preference stock	(31)	(30)
Stock-based compensation	(23)	(28)
Non-cash stock-based compensation	3	3
Issuance of preference stock		294
Redemption of preference stock		(125)
Balance, at the end of the period	14,623	13,942
Southern California Edison | Accounting for Share-Based Payments
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		317
Stock-based compensation		(34)
Southern California Edison | Common stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	2,168	2,168
Balance, at the end of the period	2,168	2,168
Southern California Edison | Additional Paid-in Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	657	652
Non-cash stock-based compensation	3	3
Issuance of preference stock		(6)
Redemption of preference stock		3
Balance, at the end of the period	660	652
Southern California Edison | Accumulated Other Comprehensive Loss
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	(20)	(22)
Other comprehensive income (loss)	2	1
Balance, at the end of the period	(18)	(21)
Southern California Edison | Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	9,433	8,804
Net income	380	325
Dividends declared on common stock	(191)	(170)
Dividends declared on preferred and preference stock	(31)	(30)
Stock-based compensation	(23)	(28)
Redemption of preference stock		(3)
Balance, at the end of the period	9,568	8,898
Southern California Edison | Preferred and Preference Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period	2,245	2,070
Issuance of preference stock		300
Redemption of preference stock		(125)
Balance, at the end of the period	$ 2,245	$ 2,245

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Variable Interest Entities (Textual) (Details) - Southern California Edison - Variable Interest Entity, Not Primary Beneficiary	3 Months Ended
	Mar. 31, 2017 USD ($) $ / shares MW	Mar. 31, 2016 USD ($)	Dec. 31, 2016 MW
SCE Power Purchase Contracts
Variable Interest Entity
Power generating capacity (in megawatts) | MW	4,928		4,383
Payments to unconsolidated VIEs for power purchase contracts	$ 140,000,000	$ 127,000,000
Trust I
Variable Interest Entity
Common stock	$ 10,000
Trust I | Trust Securities
Variable Interest Entity
Security dividend rate, (as a percent)	5.625%
Liquidation preference	$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25
Common stock	$ 10,000
Trust I | Series F Preferred Stock
Variable Interest Entity
Security dividend rate, (as a percent)	5.625%
Liquidation preference	$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Trust II
Variable Interest Entity
Common stock	$ 10,000
Trust II | Trust Securities
Variable Interest Entity
Security dividend rate, (as a percent)	5.10%
Liquidation preference	$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25
Trust II | Series G Preferred Stock
Variable Interest Entity
Security dividend rate, (as a percent)	5.10%
Liquidation preference	$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Trust III
Variable Interest Entity
Common stock	$ 10,000
Trust III | Trust Securities
Variable Interest Entity
Security dividend rate, (as a percent)	5.75%
Liquidation preference	$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25
Trust III | Series H Preferred Stock
Variable Interest Entity
Security dividend rate, (as a percent)	5.75%
Liquidation preference	$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Trust IV
Variable Interest Entity
Common stock	$ 10,000
Trust IV | Trust Securities
Variable Interest Entity
Security dividend rate, (as a percent)	5.375%
Liquidation preference	$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25
Trust IV | Series J Preferred Stock
Variable Interest Entity
Security dividend rate, (as a percent)	5.375%
Liquidation preference	$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Trust IV | Series K Preferred Stock
Variable Interest Entity
Liquidation preference	$ 300,000,000
Trust V
Variable Interest Entity
Common stock	$ 10,000
Trust V | Trust Securities
Variable Interest Entity
Security dividend rate, (as a percent)	5.45%
Liquidation preference	$ 300,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25
Trust V | Series K Preferred Stock
Variable Interest Entity
Security dividend rate, (as a percent)	5.45%
Liquidation preference	$ 300,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500

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Variable Interest Entities (Summary of Trusts' Income Statement) (Details) - Variable Interest Entity, Not Primary Beneficiary - Southern California Edison - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Trust I
Variable Interest Entity
Dividend income	$ 7	$ 7
Dividend distributions	7	7
Trust II
Variable Interest Entity
Dividend income	5	5
Dividend distributions	5	5
Trust III
Variable Interest Entity
Dividend income	4	4
Dividend distributions	4	4
Trust IV
Variable Interest Entity
Dividend income	4	4
Dividend distributions	4	4
Trust V
Variable Interest Entity
Dividend income	4	1
Dividend distributions	$ 4	$ 1

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Fair Value Measurements (Fair Value by Level) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Assets at fair value
Nuclear decommissioning trusts	$ 4,352	$ 4,242
Southern California Edison
Assets at fair value
Nuclear decommissioning trusts	$ 4,352	$ 4,242	$ 4,290	$ 4,331
Liabilities at fair value
Percentage of equity investments located in the United States (as a percent)	68.00%	70.00%
Collateralized mortgage obligations and other asset backed securities	$ 83	$ 79
Payables, net, related to investments	98	127
Southern California Edison | Fair Value, Measurements, Recurring
Assets at fair value
Derivative contracts	70	74
Other	103	33
Nuclear decommissioning trusts	4,450	4,369
Total assets	4,623	4,476
Liabilities at fair value
Derivative contracts	1,226	1,157
Netting and Collateral	0	0
Total liabilities	1,226	1,157
Net assets (liabilities)	3,397	3,319
Southern California Edison | Fair Value, Measurements, Recurring | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,537	1,547
Southern California Edison | Fair Value, Measurements, Recurring | Fixed income
Assets at fair value
Nuclear decommissioning trusts	2,741	2,616
Southern California Edison | Fair Value, Measurements, Recurring | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	172	206
Southern California Edison | Fair Value, Measurements, Recurring | Level 1
Assets at fair value
Derivative contracts	0	0
Other	103	33
Nuclear decommissioning trusts	2,778	2,448
Total assets	2,881	2,481
Liabilities at fair value
Derivative contracts	0	0
Total liabilities	0	0
Net assets (liabilities)	2,881	2,481
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,537	1,547
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Fixed income
Assets at fair value
Nuclear decommissioning trusts	1,153	865
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	88	36
Southern California Edison | Fair Value, Measurements, Recurring | Level 2
Assets at fair value
Derivative contracts	15	6
Other	0	0
Nuclear decommissioning trusts	1,672	1,921
Total assets	1,687	1,927
Liabilities at fair value
Derivative contracts	5	0
Total liabilities	5	0
Net assets (liabilities)	1,682	1,927
Southern California Edison | Fair Value, Measurements, Recurring | Level 2 | Stocks
Assets at fair value
Nuclear decommissioning trusts	0	0
Southern California Edison | Fair Value, Measurements, Recurring | Level 2 | Fixed income
Assets at fair value
Nuclear decommissioning trusts	1,588	1,751
Southern California Edison | Fair Value, Measurements, Recurring | Level 2 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	84	170
Southern California Edison | Fair Value, Measurements, Recurring | Level 3
Assets at fair value
Derivative contracts	55	68
Other	0	0
Nuclear decommissioning trusts	0	0
Total assets	55	68
Liabilities at fair value
Derivative contracts	1,221	1,157
Total liabilities	1,221	1,157
Net assets (liabilities)	(1,166)	(1,089)
Southern California Edison | Fair Value, Measurements, Recurring | Level 3 | Stocks
Assets at fair value
Nuclear decommissioning trusts	0	0
Southern California Edison | Fair Value, Measurements, Recurring | Level 3 | Fixed income
Assets at fair value
Nuclear decommissioning trusts	0	0
Southern California Edison | Fair Value, Measurements, Recurring | Level 3 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	$ 0	$ 0

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Fair Value Measurements (Textual) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 111	$ 41
Edison International Parent and Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 24	$ 23

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Fair Value Measurements (Level 3 Rollforward) (Details) - Southern California Edison - Level 3 - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Fair Value Disclosures Level 3 [Roll Forward]
Fair value of net liabilities at beginning of period	$ (1,089)	$ (1,148)
Total realized/unrealized losses:
Included in regulatory assets and liabilities	(77)	(65)
Fair value of net liabilities at end of period	(1,166)	(1,213)
Change during the period in unrealized losses related to assets and liabilities held at the end of the period	$ (102)	$ (84)

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Fair Value Measurements (Quantitative Information About Level 3 Fair Value Measurements) (Details) - Southern California Edison - Level 3 $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017 USD ($) $ / MWh $ / MMBTU MW	Dec. 31, 2016 USD ($) $ / MWh $ / MMBTU MW
Congestion revenue rights | Market simulation model and auction prices
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 55	$ 67
Fair Value, Liabilities | $	$ 0	$ 0
Congestion revenue rights | Market simulation model and auction prices | Load forecast | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, power units (in megawatts) | MW	3,708	3,708
Congestion revenue rights | Market simulation model and auction prices | Load forecast | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, power units (in megawatts) | MW	22,840	22,840
Congestion revenue rights | Market simulation model and auction prices | Power prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	3.65	3.65
Congestion revenue rights | Market simulation model and auction prices | Power prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	99.58	99.58
Congestion revenue rights | Market simulation model and auction prices | Gas prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh) | $ / MMBTU	2.51	2.51
Congestion revenue rights | Market simulation model and auction prices | Gas prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh) | $ / MMBTU	4.87	4.87
Tolling | Option model
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 0	$ 0
Fair Value, Liabilities | $	$ 1,210	$ 1,154
Tolling | Option model | Power prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	18.01	23.40
Expected volatility rate (as a percent)	26.00%	29.00%
Tolling | Option model | Power prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	45.28	51.24
Expected volatility rate (as a percent)	140.00%	71.00%
Tolling | Option model | Power prices | Weighted Average
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	30.70	34.70
Expected volatility rate (as a percent)	36.00%	40.00%
Tolling | Option model | Gas prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	16.00%	15.00%
Tolling | Option model | Gas prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	39.00%	48.00%
Tolling | Option model | Gas prices | Weighted Average
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	25.00%	20.00%

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Fair Value Measurements (Fair Value of Long-Term Debt Recorded at Carrying Value) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value of Long-Term Debt Recorded at Carrying Value [Line Items]
Carrying Value	$ 12,643	$ 11,156
Fair Value	13,894	12,368
Southern California Edison
Fair Value of Long-Term Debt Recorded at Carrying Value [Line Items]
Carrying Value	11,422	10,333
Fair Value	$ 12,665	$ 11,539

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Debt and Credit Agreements (Details) - USD ($)		1 Months Ended	3 Months Ended
	Mar. 31, 2017	Jan. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Short-term debt	$ 295,000,000		$ 295,000,000	$ 1,307,000,000
Multi-year revolving credit facility
Debt Instrument [Line Items]
Commitment	$ 1,250,000,000.00		$ 1,250,000,000.00
Weighted average interest rate (percentage)	1.18%		1.18%	0.97%
Short-term debt	$ 295,000,000		$ 295,000,000	$ 538,000,000
Southern California Edison
Debt Instrument [Line Items]
Short-term debt	$ 0		0	769,000,000
Southern California Edison | Term Loan Agreement
Debt Instrument [Line Items]
Issuance of debt		$ 300,000,000
Debt Instrument, Basis Spread on Variable Rate		0.65%
Debt Instrument, Interest Rate During Period	1.53%
Southern California Edison | Pollution-control bonds
Debt Instrument [Line Items]
Issuance of debt		$ 135,000,000
Stated interest rate (percentage)		2.625%
Southern California Edison | 4.00% First and refunding mortgage bonds due 2047 | First and refunding mortgage bonds
Debt Instrument [Line Items]
Issuance of debt	$ 700,000,000		$ 700,000,000
Stated interest rate (percentage)	4.00%		4.00%
Southern California Edison | 2.125% Senior notes due 2020 | Senior notes
Debt Instrument [Line Items]
Issuance of debt	$ 400,000,000		$ 400,000,000
Stated interest rate (percentage)	2.125%		2.125%
Southern California Edison | Multi-year revolving credit facility
Debt Instrument [Line Items]
Commitment	$ 2,750,000,000.00		$ 2,750,000,000.00
Southern California Edison | Multi-year revolving credit facility | Letters of credit
Debt Instrument [Line Items]
Outstanding letters of credit	$ 91,000,000		$ 91,000,000
Letters of credit expiration period			12 months
Southern California Edison | Multi-year revolving credit facility | Commercial paper
Debt Instrument [Line Items]
Outstanding borrowings				$ 769,000,000
Weighted average interest rate (percentage)				0.90%

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Derivative Instruments (Textual) (Details) - Southern California Edison - Electric Utility - Economic Hedges - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivative [Line Items]
Aggregate fair value of all derivative liabilities with credit-risk-related contingent features	$ 19	$ 12
Posted collateral	12	$ 12
Potential amount of collateral to be posted if contingencies triggered	8
Payables
Derivative [Line Items]
Potential amount of collateral to be posted if contingencies triggered	$ 2

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Derivative Instruments (Balance Sheet Disclosures) (Details) - Southern California Edison Company - Commodity derivative contracts - USD ($)	Mar. 31, 2017	Dec. 31, 2016
Other current assets
Net Liability
Cash collateral	$ 0
Other current liabilities
Net Liability
Collateral received		$ 2,000,000
Electric Utility
Derivative Assets
Gross amounts recognized	71,000,000	75,000,000
Gross amounts offset in the consolidated balance sheets	(1,000,000)	(1,000,000)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	70,000,000	74,000,000
Derivative Liabilities
Gross amounts recognized	1,227,000,000	1,158,000,000
Gross amounts offset in the consolidated balance sheets	(1,000,000)	(1,000,000)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	1,226,000,000	1,157,000,000
Net Liability
Gross amounts recognized	1,156,000,000	1,083,000,000
Gross amounts offset in the consolidated balance sheets	0	0
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	1,156,000,000	1,083,000,000
Electric Utility | Derivative Assets, Short-Term
Derivative Assets
Gross amounts recognized	70,000,000	74,000,000
Gross amounts offset in the consolidated balance sheets	(1,000,000)	(1,000,000)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	69,000,000	73,000,000
Electric Utility | Derivative Assets, Long-Term
Derivative Assets
Gross amounts recognized	1,000,000	1,000,000
Gross amounts offset in the consolidated balance sheets	0	0
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	1,000,000	1,000,000
Electric Utility | Derivative Liability, Short-Term
Derivative Liabilities
Gross amounts recognized	238,000,000	217,000,000
Gross amounts offset in the consolidated balance sheets	(1,000,000)	(1,000,000)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	237,000,000	216,000,000
Electric Utility | Derivative Liability, Long-Term
Derivative Liabilities
Gross amounts recognized	989,000,000	941,000,000
Gross amounts offset in the consolidated balance sheets	0	0
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	$ 989,000,000	$ 941,000,000

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Derivative Instruments (Summarization of Economic Hedging Activities) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Realized losses	$ (2)	$ (27)
Unrealized losses	$ (85)	$ (64)

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Derivative Instruments (Notional Values) (Details) - Southern California Edison - Electric Utility - Economic Hedges GWh in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2017 GWh Bcfe	Dec. 31, 2016 GWh Bcfe
Electricity options, swaps and forwards (GWh)
Derivative [Line Items]
Notional volumes of derivative instruments	1,812	1,816
Natural gas options, swaps and forwards (Bcf)
Derivative [Line Items]
Notional volumes of derivative instruments | Bcfe	123	36
Congestion revenue rights (GWh)
Derivative [Line Items]
Notional volumes of derivative instruments	79,224	93,319
Tolling arrangements (GWh)
Derivative [Line Items]
Notional volumes of derivative instruments	58,153	61,093

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Income Taxes (Tax Rate Reconciliation) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Tax Disclosures [Line Items]
Income from continuing operations before income taxes	$ 352	$ 333
Provision for income tax at federal statutory rate of 35%	124	117
Increase in income tax from:
State tax, net of federal benefit	10	6
Property-related	(113)	(79)
Change related to uncertain tax positions	(12)	(1)
Shared-based compensation	(43)	(10)
Other	(6)	(5)
Total income tax (benefit) expense from continuing operations	$ (40)	$ 28
Effective tax rate	(11.40%)	8.40%
Federal statutory rate	35.00%	35.00%
Southern California Edison
Income Tax Disclosures [Line Items]
Income from continuing operations before income taxes	$ 392	$ 367
Provision for income tax at federal statutory rate of 35%	137	128
Increase in income tax from:
State tax, net of federal benefit	13	9
Property-related	(113)	(79)
Change related to uncertain tax positions	(11)	(1)
Shared-based compensation	(8)	(8)
Other	(6)	(7)
Total income tax (benefit) expense from continuing operations	$ 12	$ 42
Effective tax rate	3.10%	11.40%
Federal statutory rate	35.00%	35.00%
Tax benefits from abandonment loss	$ 39
State
Increase in income tax from:
Shared-based compensation	6	$ 3
State | Southern California Edison
Increase in income tax from:
Shared-based compensation	1	$ 2
Tax benefits from abandonment loss	1,140
Federal | Southern California Edison
Increase in income tax from:
Tax benefits from abandonment loss	$ 698

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Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($)
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1, 2017	$ 471
Tax positions taken during the current year, Increases	10
Tax positions taken during a prior year, Increases	2
Tax positions taken during a prior year, Decreases	(10)
Tax positions taken during a prior year, Decreases for settlements during the period	(82)
Balance at March 31, 2017	391
Southern California Edison
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1, 2017	371
Tax positions taken during the current year, Increases	10
Tax positions taken during a prior year, Increases	2
Tax positions taken during a prior year, Decreases	(10)
Tax positions taken during a prior year, Decreases for settlements during the period	(78)
Balance at March 31, 2017	$ 295

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Compensation and Benefit Plans (Textual) (Details) - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2017	Mar. 31, 2017
Pension Plans
Pension and Other Postretirement Benefits
Employer contributions		$ 25.0
Estimated future contributions in remainder of year		111.0
PBOP Plan
Pension and Other Postretirement Benefits
Employer contributions		5.0
Estimated future contributions in remainder of year		16.0
Southern California Edison | Pension Plans
Pension and Other Postretirement Benefits
Employer contributions		21.0
Estimated future contributions in remainder of year		$ 64.0
Forecast | Pension Plans
Pension and Other Postretirement Benefits
Settlement loss	$ 7.7
Settlement loss, net of tax	$ 4.6

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Compensation and Benefit Plans (Expense Components) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Pension Plans
Pension and Other Postretirement Benefits
Service cost	$ 36	$ 39
Interest cost	41	44
Expected return on plan assets	(53)	(56)
Amortization of prior service cost	1	1
Amortization of net loss	5	9
Expense under accounting standards	30	37
Regulatory adjustment	(3)	(9)
Total expense recognized	27	28
Net loss reclassified	3	3
PBOP Plan
Pension and Other Postretirement Benefits
Service cost	9	10
Interest cost	24	26
Expected return on plan assets	(27)	(28)
Amortization of prior service cost	(1)	(1)
Expense under accounting standards	5	7
Southern California Edison | Pension Plans
Pension and Other Postretirement Benefits
Service cost	35	38
Interest cost	37	41
Expected return on plan assets	(50)	(53)
Amortization of prior service cost	1	1
Amortization of net loss	4	8
Expense under accounting standards	27	35
Regulatory adjustment	(3)	(9)
Total expense recognized	24	26
Net loss reclassified	2	2
Southern California Edison | PBOP Plan
Pension and Other Postretirement Benefits
Service cost	9	10
Interest cost	24	26
Expected return on plan assets	(27)	(28)
Amortization of prior service cost	(1)	(1)
Expense under accounting standards	$ 5	$ 7

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Investments (Amortized Cost and Fair Value of Nuclear Decommissioning Trusts) (Details) - Southern California Edison - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	$ 2,867	$ 2,784
Fair Value	4,352	4,242
Stocks
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	291	319
Fair Value	1,537	1,547
Municipal bonds
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	645	659
Fair Value	753	766
U.S. government and agency securities
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	1,308	1,131
Fair Value	1,380	1,191
Corporate bonds
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	552	600
Fair Value	608	659
Short-term investments and receivables/payables
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	71	75
Fair Value	74	79
Repurchase agreement	$ 36	$ 114

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Investments (Nuclear Decommissioning Trusts) (Details) - Southern California Edison - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Other Investments [Line Items]
Unrealized holding gains, net of losses	$ 1,500	$ 1,500
Deferred income taxes related to unrealized gains	373
Nuclear decommissioning trusts	$ 4,000

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Investments (Summary of Changes in Fair Value of the Nuclear Decommissioning Trusts) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period	$ 4,242
Balance at end of period	4,352
Southern California Edison
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period	4,242	$ 4,331
Gross realized gains	99	17
Gross realized losses	(16)	(3)
Unrealized gains, net of losses	27	59
Other-than-temporary impairments	(1)	(7)
Interest and dividends	28	29
Income taxes	0	(18)
Decommissioning disbursements	(26)	(116)
Administrative expenses and other	(1)	(2)
Balance at end of period	$ 4,352	$ 4,290

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Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Current regulatory assets	$ 394	$ 350
Long-term regulatory assets	7,674	7,455
Environmental remediation
Regulatory Assets [Line Items]
Long-term regulatory assets	125	126
Southern California Edison
Regulatory Assets [Line Items]
Current regulatory assets	394	350
Long-term regulatory assets	7,674	7,455
Total regulatory assets	8,068	7,805
Southern California Edison | Regulatory balancing accounts
Regulatory Assets [Line Items]
Current regulatory assets	139	135
Long-term regulatory assets	68	66
Southern California Edison | Energy derivatives
Regulatory Assets [Line Items]
Current regulatory assets	186	150
Long-term regulatory assets	996	947
Southern California Edison | Unamortized investments, net of accumulated amortization
Regulatory Assets [Line Items]
Current regulatory assets	37	49
Southern California Edison | Other
Regulatory Assets [Line Items]
Current regulatory assets	32	16
Long-term regulatory assets	11	7
Southern California Edison | Deferred income taxes, net of liabilities
Regulatory Assets [Line Items]
Long-term regulatory assets	4,689	4,478
Southern California Edison | Pensions and other postretirement benefits
Regulatory Assets [Line Items]
Long-term regulatory assets	711	710
Southern California Edison | Unamortized investments, net of accumulated amortization
Regulatory Assets [Line Items]
Long-term regulatory assets	79	80
Southern California Edison | San Onofre
Regulatory Assets [Line Items]
Long-term regulatory assets	815	857
Southern California Edison | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Long-term regulatory assets	$ 180	$ 184

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Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 804	$ 756
Long-term regulatory liabilities	5,910	5,726
Southern California Edison
Regulatory Liabilities [Line Items]
Current regulatory liabilities	804	756
Long-term regulatory liabilities	5,910	5,726
Total regulatory liabilities	6,714	6,482
Southern California Edison | Regulatory balancing accounts
Regulatory Liabilities [Line Items]
Current regulatory liabilities	740	736
Long-term regulatory liabilities	1,278	1,180
Southern California Edison | San Onofre MHI arbitration award
Regulatory Liabilities [Line Items]
Current regulatory liabilities	47	0
Southern California Edison | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	20
Long-term regulatory liabilities	59	60
Southern California Edison | Costs of removal
Regulatory Liabilities [Line Items]
Long-term regulatory liabilities	2,838	2,847
Southern California Edison | Recoveries in excess of ARO liabilities
Regulatory Liabilities [Line Items]
Long-term regulatory liabilities	$ 1,735	$ 1,639

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Regulatory Assets and Liabilities (Schedule of Net Regulatory Balancing Accounts) (Details) - Southern California Edison - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Regulatory balancing accounts | Energy resource recovery account
Regulatory Assets and Liabilities
Asset (liability)	$ 30	$ (20)
Regulatory balancing accounts | New system generation balancing account
Regulatory Assets and Liabilities
Asset (liability)	(97)	(6)
Refunds of excess revenue | Significant Components
Regulatory Assets and Liabilities
Asset (liability)	(1,811)	(1,715)
Refunds of excess revenue | Public purpose programs and energy efficiency programs
Regulatory Assets and Liabilities
Asset (liability)	(1,056)	(992)
Refunds of excess revenue | Tax accounting memorandum account and pole loading balancing account
Regulatory Assets and Liabilities
Asset (liability)	(136)	(142)
Refunds of excess revenue | Base rate recovery balancing account
Regulatory Assets and Liabilities
Asset (liability)	(360)	(426)
Refunds of excess revenue | Department of Energy litigation memorandum account
Regulatory Assets and Liabilities
Asset (liability)	(123)	(122)
Refunds of excess revenue | Greenhouse gas auction revenue
Regulatory Assets and Liabilities
Asset (liability)	(3)	31
Refunds of excess revenue | FERC balancing accounts
Regulatory Assets and Liabilities
Asset (liability)	(93)	(69)
Refunds of excess revenue | Other
Regulatory Assets and Liabilities
Asset (liability)	$ 27	$ 31

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Commitments and Contingencies (Third-Party Power Purchase Agreements) (Details) - Southern California Edison - Commitments meeting critical contract provisions $ in Millions	Mar. 31, 2017 USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Estimated commitments in next twelve months	$ 48
Estimated commitments in two years	116
Estimated commitments in three years	117
Estimated commitments in four years	119
Estimated commitments in five years	120
Estimated commitments after five years	$ 955

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Commitments and Contingencies (Contingencies) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Regulatory assets	$ 7,674	$ 7,455
Southern California Edison
Regulatory Assets [Line Items]
Regulatory assets	7,674	7,455
Southern California Edison | San Onofre
Regulatory Assets [Line Items]
Regulatory assets	$ 815	$ 857

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Commitments and Contingencies (MHI Claims) (Details) - USD ($)		1 Months Ended
	Mar. 13, 2017	Apr. 30, 2016	Oct. 31, 2013	Jun. 30, 2010
Southern California Edison
Schedule Of Commitments And Contingencies [Line Items]
Damages sought				$ 112,000,000
Initial recovery rewarded		$ 124,000,000
San Onofre | Southern California Edison | Mitsubishi Heavy Industries Ltd
Schedule Of Commitments And Contingencies [Line Items]
Initial recovery rewarded	$ 52,000,000
Net recovery	$ 47,000,000
San Onofre | Southern California Edison | Mitsubishi Heavy Industries Ltd | Minimum
Schedule Of Commitments And Contingencies [Line Items]
Damages sought			$ 4,000,000,000
San Onofre | Mitsubishi Heavy Industries Ltd
Schedule Of Commitments And Contingencies [Line Items]
Asserted counterclaim			$ 41,000,000

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Commitments and Contingencies (Environmental Remediation) (Details) - Southern California Edison	3 Months Ended
	Mar. 31, 2017 USD ($) site	Mar. 31, 2016 USD ($)
Schedule Of Commitments And Contingencies [Line Items]
Identified material sites for environmental remediation (in number of sites) | site	19
Minimum costs to be identified site	$ 1,000,000
Minimum liability for environmental remediation for material sites	$ 127,000,000
Immaterial sites for environmental remediation (in number of sites) | site	17
Environmental remediation liability	$ 130,000,000
Regulatory assets related to environmental remediation	125,000,000
Portion of recorded liability recoverable from incentive mechanism	$ 47,000,000
Percentage of environmental remediation costs recoverable through an incentive mechanism (as a percent)	90.00%
Liability incurred at majority of the remaining sites through customer rates	$ 78,000,000
Environmental remediation costs to be recovered (as a percent)	100.00%
Amount that cleanup costs could exceed recorded liability for identified material sites	$ 149,000,000
Amount that cleanup costs could exceed recorded liability for immaterial sites	$ 8,000,000
Remediation cost estimates (period)	5 years
Environmental remediation costs	$ 2,000,000	$ 1,000,000
Minimum
Schedule Of Commitments And Contingencies [Line Items]
Minimum liability for environmental remediation for immaterial sites	3,000,000
Expected annual environmental remediation costs	$ 5,000,000
Maximum
Schedule Of Commitments And Contingencies [Line Items]
Maximum expected period for cleanup of identified sites (in years)	30 years
Expected annual environmental remediation costs	$ 18,000,000
San Onofre
Schedule Of Commitments And Contingencies [Line Items]
Minimum liability for environmental remediation for material sites	$ 75,000,000

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Commitments and Contingencies (Nuclear Insurance) (Details) - Nuclear Insurance	3 Months Ended
	Mar. 31, 2017 USD ($)
Schedule Of Commitments And Contingencies [Line Items]
Federal limit on public liability claims from nuclear incident, approximate	$ 13,400,000,000
SCE and other owners of San Onofre and Palo Verde | San Onofre and Palo Verde
Schedule Of Commitments And Contingencies [Line Items]
Loss limit, property damage insurance, federal minimum requirement	1,060,000,000
Southern California Edison
Schedule Of Commitments And Contingencies [Line Items]
Limit on assessment of retrospective premium adjustments, per year, approximate	52,000,000
Maximum assessment per each nuclear incident	255,000,000
Maximum yearly assessment per nuclear incident	$ 38,000,000

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Commitments and Contingencies (Wildfire Insurance) (Details) - Southern California Edison	Mar. 31, 2017 USD ($)
Schedule Of Commitments And Contingencies [Line Items]
Threshold for wildfire claims (new lines for additional coverage)	$ 1,000,000,000
Self-insured retention per wildfire occurrence	$ 10,000,000

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Commitments and Contingencies (Spent Nuclear Fuel) (Details) - USD ($) $ in Millions	1 Months Ended
	Apr. 30, 2016	Jun. 30, 2010	Feb. 28, 2017	Sep. 30, 2016
SCE and other owners of San Onofre and Palo Verde
Schedule Of Commitments And Contingencies [Line Items]
Damages sought		$ 142
Damage award	$ 162
Southern California Edison
Schedule Of Commitments And Contingencies [Line Items]
Damages sought		$ 112
Damage award	$ 124
Claim to recover damages incurred			$ 43	$ 56

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Pension and PBOP – net loss:
Other	$ 2	$ 0
Accumulated Other Comprehensive Loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(53)	(56)
Pension and PBOP – net loss:
Ending Balance	(49)	(54)
Accumulated Other Comprehensive Loss | Southern California Edison
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(20)	(22)
Pension and PBOP – net loss:
Ending Balance	(18)	(21)
Accumulated Defined Benefit Plans Adjustment
Pension and PBOP – net loss:
Reclassified from accumulated other comprehensive loss	2	2
Other	2	0
Change	4	2
Accumulated Defined Benefit Plans Adjustment | Southern California Edison
Pension and PBOP – net loss:
Reclassified from accumulated other comprehensive loss	1	1
Other	1	0
Change	$ 2	$ 1

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Interest and Other Income and Other Expenses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Interest and other income:
Interest and other income	$ 33	$ 31
Other expenses:
Total Edison International other expenses	(8)	(6)
Southern California Edison
Interest and other income:
Equity allowance for funds used during construction	19	22
Increase in cash surrender value of life insurance policies	12	7
Interest income	1	0
Other	1	2
Total SCE interest and other income	33	31
Interest and other income	33	31
Other expenses:
Civic, political and related activities and donations	(4)	(5)
Other	(3)	0
Total SCE other expenses	(7)	(5)
Total Edison International other expenses	(7)	(5)
Edison International Parent and Other
Other expenses:
Other expenses of Edison International Parent and Other	$ (1)	$ (1)

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Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$ 167	$ 158
Tax payments, net of refunds	0	2
Common stock
Dividends declared but not paid:
Dividends declared but not paid	177	156
Preferred and preference stock
Dividends declared but not paid:
Dividends declared but not paid	1	1
Southern California Edison
Cash payments for interest and taxes:
Interest, net of amounts capitalized	152	149
Tax payments, net of refunds	0	11
Non-cash financing and investing activities:
Accrued capital expenditures	275	360
Southern California Edison | Common stock
Dividends declared but not paid:
Dividends declared but not paid	0	0
Southern California Edison | Preferred and preference stock
Dividends declared but not paid:
Dividends declared but not paid	$ 1	$ 1