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 June 30, 2016
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from                        to

Commission File Number	Exact Name of Registrant as specified in its charter	State or Other Jurisdiction of Incorporation or Organization	IRS Employer Identification Number
1-9936	EDISON INTERNATIONAL	California	95-4137452
1-2313	SOUTHERN CALIFORNIA EDISON COMPANY	California	95-1240335

EDISON INTERNATIONAL	SOUTHERN CALIFORNIA EDISON COMPANY
2244 Walnut Grove Avenue (P.O. Box 976) Rosemead, California 91770 (Address of principal executive offices)	2244 Walnut Grove Avenue (P.O. Box 800) Rosemead, California 91770 (Address of principal executive offices)
(626) 302-2222 (Registrant's telephone number, including area code)	(626) 302-1212 (Registrant's telephone number, including area code)

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 or a smaller reporting company. See the definitions of "accelerated filer," "large accelerated filer," and "smaller reporting company" in Rule 12b-12 of the Exchange Act. (Check One):
Edison International	Large Accelerated Filer þ	Accelerated Filer ¨	Non-accelerated Filer ¨	Smaller Reporting Company ¨
Southern California Edison Company	Large Accelerated Filer ¨	Accelerated Filer ¨	Non-accelerated Filer þ	Smaller Reporting Company ¨

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

Edison International        Yes ¨ No 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 July 26, 2016:
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				4	Part I, Item 2
	MANAGEMENT OVERVIEW			4
		Highlights of Operating Results		4
		Capital Program		5
	RESULTS OF OPERATIONS			6
	Southern California Edison Company			6
		Three months ended June 30, 2016 versus June 30, 2015		6
			Earning Activities	7
			Cost-Recovery Activities	7
		Six months ended June 30, 2016 versus June 30, 2015		8
			Earning Activities	8
			Cost-Recovery Activities	9
	Supplemental Operating Revenue Information			9
	Income Taxes			9
	Edison International Parent and Other			10
		Income from Continuing Operations		10
	LIQUIDITY AND CAPITAL RESOURCES			10
	Southern California Edison Company			10
		Available Liquidity		10
		Regulatory Proceedings		11
		Capital Investment Plan		11
		Dividend Restrictions		12
		Margin and Collateral Deposits		12
	Edison International Parent and Other			13
	Historical Cash Flows			14
		Southern California Edison Company		14
		Edison International Parent and Other		16
	Contingencies			17
		Environmental Remediation		17
	MARKET RISK EXPOSURES			17
	Commodity Price Risk			17
	Credit Risk			17
	CRITICAL ACCOUNTING ESTIMATES AND POLICIES			18
	NEW ACCOUNTING GUIDANCE			18
RISK FACTORS				18	Part I, Item 1A
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY				18
	Regulatory Risks			18
	Competitive and Market Risks			19
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK				19	Part I, Item 3

i

FINANCIAL STATEMENTS			20	Part I, Item 1
	Edison International Consolidated Statements of Income		20
	Edison International Consolidated Statements of Comprehensive Income		21
	Edison International Consolidated Balance Sheets		22
	Edison International Consolidated Statements of Cash Flows		24
	SCE Consolidated Statements of Income		25
	SCE Consolidated Statements of Comprehensive Income		25
	SCE Consolidated Balance Sheets		26
	SCE Consolidated Statements of Cash Flows		28
	NOTES TO CONSOLIDATED FINANCIAL STATEMENTS		29
		Note 1. Summary of Significant Accounting Policies	29
		Note 2. Consolidated Statements of Changes in Equity	32
		Note 3. Variable Interest Entities	33
		Note 4. Fair Value Measurements	35
		Note 5. Debt and Credit Agreements	39
		Note 6. Derivative Instruments	39
		Note 7. Income Taxes	41
		Note 8. Compensation and Benefit Plans	42
		Note 9. Investments	45
		Note 10. Regulatory Assets and Liabilities	46
		Note 11. Commitments and Contingencies	47
		Note 12. Preferred and Preference Stock of SCE	51
		Note 13. Accumulated Other Comprehensive Loss	52
		Note 14. Interest and Other Income and Other Expenses	52
		Note 15. Supplemental Cash Flows Information	53
CONTROLS AND PROCEDURES			53	Part I, Item 4
	Disclosure Controls and Procedures		53
	Changes in Internal Control Over Financial Reporting		53
	Jointly Owned Plant		53
LEGAL PROCEEDINGS			53	Part II, Item 1
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS			54	Part II, Item 2
	Purchases of Equity Securities by Edison International and Affiliated Purchasers		54
EXHIBITS			55	Part II, Item 6
SIGNATURES			56

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.

AFUDC	allowance for funds used during construction
2015 Form 10-K	Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 2015
ALJ	administrative law judge
APS	Arizona Public Service Company
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
CAA	Clean Air Act
CAISO	California Independent System Operator
CARB	California Air Resources Board
Competitive Businesses	businesses focused on providing energy solutions, including distributed generation and/or storage, to commercial and industrial customers; engaging in competitive transmission opportunities; and exploring distributed water treatment and recycling.
CPUC	California Public Utilities Commission
CRRs	congestion revenue rights
DOE	U.S. Department of Energy
Edison Energy	Edison Energy, LLC, a wholly-owned subsidiary of Edison Energy Group and one of the Competitive Businesses
Edison Energy Group	Edison Energy Group, Inc., the holding company for the Competitive Businesses
EME	Edison Mission Energy
EME Settlement Agreement	Settlement Agreement entered into by Edison International, EME, and the Consenting Noteholders in February 2014
EMG	Edison Mission Group Inc.
EPS	earnings per share
ERRA	energy resource recovery account
FERC	Federal Energy Regulatory Commission
Four Corners	coal fueled electric generating facility located in Farmington, New Mexico in which SCE held a 48% ownership interest
GAAP	generally accepted accounting principles
GHG	greenhouse gas
GRC	general rate case
GWh	gigawatt-hours
HLBV	hypothetical liquidation at book value
IRS	Internal Revenue Service
Joint Proxy Statement	Edison International's and SCE's definitive Proxy Statement filed with the SEC in connection with Edison International's and SCE's Annual Shareholders' Meeting held on April 28, 2016
MD&A	Management's Discussion and Analysis of Financial Condition and Results of Operations in this report
MHI	Mitsubishi Heavy Industries, Ltd. and a related company
Moody's	Moody's Investors Service
MW	megawatts
MWh	megawatt-hours
NAAQS	national ambient air quality standards
NEIL	Nuclear Electric Insurance Limited
NEM	net energy metering

iii

NERC	North American Electric Reliability Corporation
NRC	Nuclear Regulatory Commission
ORA	CPUC's Office of Ratepayers Advocates
OII	Order Instituting Investigation
Palo Verde	large pressurized water 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)
PG&E	Pacific Gas & Electric Company
QF(s)	qualifying facility(ies)
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, The Utility Reform Network, the CPUC's Office of Ratepayer Advocates and SDG&E, which was later joined by the Coalition of California Utility Employees and Friends of the Earth, (together, the "Settling Parties"), 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
TURN	The Utility Reform Network
US EPA	U.S. Environmental Protection Agency
VIE(s)	variable interest entity(ies)

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 statement that does not directly relate to a historical or current fact. Other information distributed by Edison International and SCE that is incorporated in this report, or that refers to or incorporates this report, may also contain forward-looking statements. In this report and elsewhere, the words "expects," "believes," "anticipates," "estimates," "projects," "intends," "plans," "probable," "may," "will," "could," "would," "should," and variations of such words and similar expressions, or discussions of strategy or of plans, are intended to identify forward-looking statements. Such statements necessarily involve risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of the risks, uncertainties and other important factors that could cause results to differ from those currently expected, or that otherwise could impact Edison International and SCE, include, but are not limited to the:

• ability of SCE to recover its costs in a timely manner from its customers through regulated rates, including regulatory assets related to San Onofre;

• decisions and other actions by the CPUC, the FERC, the NRC and other regulatory authorities, including the determinations of authorized rates of return or return on equity, 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;

• 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 technological advancements in the generation, storage, transmission, distribution and use of electricity, and supported by public policy, government regulations and incentives;

• risks inherent in the construction of transmission and distribution infrastructure replacement and expansion projects, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, power curtailment costs (payments due under power contracts in the event there is insufficient transmission to enable acceptance of power delivery), and governmental approvals;

• risks associated with the operation of transmission and distribution assets and power generating facilities including: public safety issues, failure, availability, efficiency, and output of equipment and availability and cost of spare parts;

• risks associated with the retirement and decommissioning of nuclear generating facilities;

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

• ability of Edison International to develop its Competitive Businesses, manage new business risks, and recover and earn a return on its investment in newly developed or acquired businesses;

• cost and availability of electricity, including the ability to procure sufficient resources to meet expected customer needs in the event of power plant outages or significant counterparty defaults under power-purchase agreements;

• environmental laws and regulations, at both the state and federal levels, or changes in the application of those laws, that could require additional expenditures or otherwise affect the cost and manner of doing business;

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

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

• governmental, statutory, regulatory or administrative changes or initiatives affecting the electricity industry, including the market structure rules applicable to each market adopted by the CAISO, WECC, NERC, and adjoining regions;

• availability and creditworthiness of counterparties and the resulting effects on liquidity in the power and fuel markets and/or the ability of counterparties to pay amounts owed in excess of collateral provided in support of their obligations;

• cost and availability of labor, equipment and materials;

1

• 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 MD&A and in Edison International's and SCE's combined 2015 Form 10-K, including the "Risk Factors" section. Readers are urged to read this entire report, including the information incorporated by reference, as well as the 2015 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. Additionally, Edison International and SCE provide direct links to SCE's regulatory filings with the CPUC and the FERC in open proceedings most important to investors at www.edisoninvestor.com (SCE Regulatory Highlights) so that such filings are available to all investors upon SCE filing with the relevant agency.

The MD&A for the six months ended June 30, 2016 discusses material changes in the consolidated financial condition, results of operations and other developments of Edison International and SCE since December 31, 2015, and as compared to the six months ended June 30, 2015. This discussion presumes that the reader has read or has access to Edison International's and SCE's MD&A for the calendar year 2015 (the "year-ended 2015 MD&A"), which was included in the 2015 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

(This page has been left blank intentionally.)

3

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

MANAGEMENT OVERVIEW

Highlights of Operating Results

Edison International is the parent holding company of SCE. SCE is a public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area of southern California. Edison International is also the parent company of subsidiaries that are engaged in competitive businesses focused on providing energy solutions to commercial and industrial customers, including distributed resources, engaging in transmission opportunities, and exploring distributed water treatment and recycling (the "Competitive Businesses"). Such business activities are currently not material to report as a separate business segment. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its competitive subsidiaries. Unless otherwise described, all of the information contained in this report relates to both filers.

	Three months ended June 30,									Six months ended June 30,
(in millions)	2016			2015			Change			2016			2015			Change
Net income (loss) attributable to Edison International
Continuing operations
SCE	$	315		$	384		$	(69	)	$	601		$	689		$	(88	)
Edison International Parent and Other	(37		)	(5		)	(32		)	(54		)	(11		)	(43		)
Discontinued operations	(2		)	—			(2		)	(1		)	—			(1		)
Edison International	276			379			(103		)	546			678			(132		)
Less: Non-core items
SCE	—			—			—			—			—			—
Edison International Parent and Other	2			1			1			4			6			(2		)
Discontinued operations	(2		)	—			(2		)	(1		)	—			(1		)
Total non-core items	—			1			(1		)	3			6			(3		)
Core earnings (losses)
SCE	315			384			(69		)	601			689			(88		)
Edison International Parent and Other	(39		)	(6		)	(33		)	(58		)	(17		)	(41		)
Edison International	$	276		$	378		$	(102	)	$	543		$	672		$	(129	)

Edison International's earnings are prepared in accordance with GAAP used in the United States. Management uses core earnings internally for financial planning and for analysis of performance. Core earnings (losses) are also used when communicating with investors and analysts regarding Edison International's earnings results to facilitate comparisons of the Company's performance from period to period. Core earnings (losses) are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (losses) are defined as earnings attributable to Edison International shareholders less non-core items. Non-core items include income or loss from discontinued operations, income resulting from allocation of losses to tax equity investors under the hypothetical liquidation at book value ("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.

SCE's earnings for the second quarter and six months ended June 30, 2016 decreased by $69 million and $88 million, respectively, which includes lower income tax benefits partially offset by the implementation of the 2015 GRC decision and 2016 incremental return on the pole loading rate base. The year-to-date variance also includes higher operation and maintenance costs.

During the second quarter of 2015, SCE recorded $100 million of income tax benefits from revisions to liabilities for uncertain tax positions (see "Results of Operations" for further information).

4

During the first six months of 2015, pending the outcome of the 2015 GRC decision, SCE recognized GRC-related revenue largely based on the 2014 authorized revenue requirement. During the third and fourth quarters of 2015, SCE recorded revenue refunds to customers which totaled $451 million to reflect the final decision in the 2015 GRC. The estimated amount of the refund to customers attributable to the second quarter and six months ended June 30, 2015, but subsequently recorded in 2015, was approximately $35 million ($21 million after-tax) and $70 million ($42 million after-tax), respectively. In addition, SCE's results of operations for the three and six months ended June 30, 2016 included an increase in revenue of approximately $50 million ($30 million after-tax) and $96 million ($57 million after-tax), respectively, from the escalation mechanism set forth in the final 2015 GRC decision. The annual escalation increase implemented in customer rates for 2016 was $203 million. SCE's results of operations for the three and six months ended June 30, 2015 were largely based on 2014 authorized base revenue requirements included in customer rates.

Edison International Parent and Other losses from continuing operations for the second quarter and six months ended June 30, 2016 increased by $32 million and $43 million, respectively. Losses for the second quarter consisted of $33 million of higher core losses and $1 million of higher non-core earnings. Losses for the six months ended June 30, 2016 consisted of $41 million of higher core losses and $2 million of lower non-core earnings. During the second quarter of 2016, Edison International Parent and Other recorded an after-tax charge of $13 million related to the buy-out of an earn-out provision with the former shareholders of a company acquired by Edison Energy at the end of 2015. The buy-out was completed, together with modification to employment contracts, in order to align long-term incentive compensation. In addition, core losses included higher operating and development costs and lower revenue and gross margin from the sale of solar systems at Edison Energy Group. Results during 2015 includedincome from Edison Capital's investments in affordable housing projects which were sold at the end of 2015.

Consolidated non-core items included income of $2 million and $4 million for the three and six months ended June 30, 2016, respectively, compared to income of $1 million and $6 million for the same periods in 2015. The income was related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method. Edison International reflected in core earnings the operating results of the solar rooftop projects, related financings and the priority return to the tax equity investor. The losses allocated to the tax equity investor under HLBV accounting method results in income allocated to subsidiaries of Edison International, neither of which is due to the operating performance of the projects but rather due to the allocation of income tax attributes under the tax equity financing. Accordingly, Edison International has included the non-operating allocation of income as a non-core item. For further information on HLBV, see the 2015 Form 10-K, "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."

Capital Program

SCE forecasts capital expenditures for 2016 – 2017 in the range of $7.9 billion to $8.1 billion. The low end of the range reflects a 12% reduction in FERC projects using management judgment, based on historical experience. SCE's 2016 – 2017 forecast for major capital expenditures are set forth in the table below:

(in millions)	2016		2017		2016 – 2017 Total
Transmission	$	534	$	1,000	$	1,534
Distribution	2,984		3,079		6,063
Generation	244		217		461
Total estimated capital expenditures	$	3,762	$	4,296	$	8,058
Total estimated capital expenditures for 2016 – 2017 (using the range discussed above)	$	3,694	$	4,174	$	7,868

Capital expenditures for projects under CPUC jurisdiction are recovered through the authorized revenue requirement in SCE's GRC or through other CPUC-authorized mechanisms. Recovery for 2016 – 2017 planned expenditures for projects under FERC jurisdiction will be pursued through FERC-authorized mechanisms.

SCE is experiencing delays, mainly due to licensing, with certain of its transmission projects, notably the Riverside Transmission Reliability Project, Alberhill System and Mesa Substation. As a result, approximately $300 million of 2016 capital expenditures have been delayed. Approximately $100 million of these capital expenditures will be made up in 2017 and the remaining $200 million will be reflected in our forecast once SCE files its 2018 GRC application. SCE will file its 2018 GRC application in September 2016, which will include a forecast of capital expenditures and rate base for 2018 – 2020.

5

Changes to the route or location, adoption of any undergrounding options or other significant modification to the licensing or construction plans could create additional costs and further delay the completion of the projects discussed above. For further information regarding the capital program, see "Liquidity and Capital Resources—Capital Investment Plan" and the year-ended 2015 MD&A, "Management Overview—Capital Program."

SCE's forecasted rate base for 2016 and 2017 is as follows:

(in millions)	2016		2017
Based on total estimated capital expenditures	$	25,012	$	26,615
Based on total estimated capital expenditures for 2016 – 2017 (using the range discussed above)	24,944		26,425

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 revenue or penalties related to incentive mechanisms, other operating revenue, and regulatory charges or disallowances.

• Cost-recovery activities – representing CPUC- and FERC-authorized balancing accounts which allow for recovery of specific project or program costs, subject to reasonableness review or compliance with upfront standards. Cost-recovery activities include rates which provide recovery, subject to reasonableness review of, among other things, fuel costs, purchased power costs, public purpose related-program costs (including energy efficiency and demand-side management programs) and certain operation and maintenance expenses.

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

Three months ended June 30, 2016 versus June 30, 2015

	Three months ended June 30, 2016								Three months ended June 30, 2015
(in millions)	Earning Activities			Cost- Recovery Activities		Total Consolidated			Earning Activities			Cost- Recovery Activities			Total Consolidated
Operating revenue	$	1,509		$	1,259	$	2,768		$	1,596		$	1,305		$	2,901
Purchased power and fuel	—			1,064		1,064			—			1,078			1,078
Operation and maintenance	492			195		687			495			229			724
Depreciation, decommissioning and amortization	503			—		503			481			—			481
Property and other taxes	85			—		85			82			—			82
Total operating expenses	1,080			1,259		2,339			1,058			1,307			2,365
Operating income	429			—		429			538			(2		)	536
Interest expense	(134		)	—		(134		)	(132		)	1			(131		)
Other income and expenses	22			—		22			13			1			14
Income before income taxes	317			—		317			419			—			419
Income tax expense	(29		)	—		(29		)	7			—			7
Net income	346			—		346			412			—			412
Preferred and preference stock dividend requirements	31			—		31			28			—			28
Net income available for common stock	$	315		$	—	$	315		$	384		$	—		$	384
Core earnings1						$	315								$	384
Non-core earnings						—									—
Total SCE GAAP earnings						$	315								$	384

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

6

Earning Activities

Earning activities were primarily affected by the following:

• Lower operating revenue of $87 million primarily due to the following:

• During the second quarter of 2016, SCE recorded a revenue refund to customers of $133 million for 2012 – 2014 incremental tax benefits related to repair deductions (offset in income taxes as discussed below). This revenue refund resulted from the CPUC's approval of SCE's request to refund incremental tax repair deductions that were not addressed in SCE's 2015 GRC decision. See "Liquidity and Capital Resources—Regulatory Proceedings—Tax Repair Deductions and Memorandum Account" for further information.

• A decrease in revenue of approximately $20 million for 2016 incremental tax benefits recognized through the tax accounting memorandum account ("TAMA") and the pole loading balancing account (offset in income taxes as discussed below). In addition, in 2016, SCE recorded $15 million ($9 million after-tax) of incremental return on the pole loading rate base in this balancing account. During the second quarter of 2015, there was no incremental return on pole loading rate base due to the timing of the final GRC decision.

• An increase in FERC-related revenue of $19 million primarily due to higher operating costs including amortization of the regulatory asset associated with the Coolwater-Lugo transmission project (see "Liquidity and Capital Resources—Capital Investment Plan—Major Transmission Projects—Coolwater-Lugo" for further information) and rate base growth partially offset by a $15 million increase in 2015 revenue due to a change in estimate under the FERC formula rate mechanism.

• An increase in CPUC revenue of approximately $15 million primarily due to the implementation of the 2015 GRC decision. During the second quarter of 2016, SCE increased authorized revenue approximately $50 million based on the escalation mechanism set forth in the 2015 GRC decision. This increase was partially offset by approximately $35 million of the refund to customers attributable to the second quarter of 2015 as a result of the finalization of the 2015 GRC decision (see "Highlights of Operating Results" for further information).

• An increase of $9 million primarily due to tax benefits recognized in 2015 related to net operating loss carrybacks for San Onofre decommissioning costs resulting in a reduction in revenue in 2015 (offset in income taxes).

• Lower operation and maintenance costs of $3 million primarily related to lower labor costs due to the workforce reductions and lower legal costs. These lower costs were partially offset by a planned outage and upgrades at the Mountainview plant and costs associated with the pole loading program. The pole loading program costs are recovered in revenue (for further information see the year-ended 2015 MD&A, "Management Overview—Regulatory Proceedings—2015 General Rate Case").

• Higher depreciation, decommissioning and amortization expense of $22 million primarily related to depreciation on transmission and distribution investments and amortization of the regulatory asset related to the Coolwater-Lugo, as discussed above.

• Higher other income and expenses of $9 million primarily due to higher insurance benefits in 2016. See "Notes to Consolidated Financial Statements—Note 14. Interest and Other Income and Other Expenses" for further details.

• Lower income taxes of $36 million primarily due to lower pre-tax income and the following discrete items:

• Higher income tax benefits in 2016 primarily related to $79 million of flow-through incremental tax benefits for 2012 – 2014 to customers and $12 million of repair deductions for TAMA and pole loading balancing accounts (both offset in revenue above).

• A change in liabilities related to uncertain tax positions related to repair deductions, which resulted in income tax benefits of $100 million during the second quarter of 2015.

Cost-Recovery Activities

Cost-recovery activities were primarily affected by the following:

• Lower operation and maintenance expense of $34 million primarily due to lower transmission access charges and lower spending on various public purpose programs.

7

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

Six months ended June 30, 2016 versus June 30, 2015

	Six months ended June 30, 2016								Six months ended June 30, 2015
(in millions)	Earning Activities			Cost- Recovery Activities		Total Consolidated			Earning Activities			Cost- Recovery Activities			Total Consolidated
Operating revenue	$	3,031		$	2,173	$	5,204		$	3,159		$	2,250		$	5,409
Purchased power and fuel	—			1,858		1,858			—			1,864			1,864
Operation and maintenance	975			315		1,290			958			388			1,346
Depreciation, decommissioning and amortization	978			—		978			943			—			943
Property and other taxes	176			—		176			170			—			170
Total operating expenses	2,129			2,173		4,302			2,071			2,252			4,323
Operating income	902			—		902			1,088			(2		)	1,086
Interest expense	(265		)	—		(265		)	(267		)	1			(266		)
Other income and expenses	46			—		46			39			1			40
Income before income taxes	683			—		683			860			—			860
Income tax expense	21			—		21			115			—			115
Net income	662			—		662			745			—			745
Preferred and preference stock dividend requirements	61			—		61			56			—			56
Net income available for common stock	$	601		$	—	$	601		$	689		$	—		$	689
Core earnings1						$	601								$	689
Non-core earnings						—									—
Total SCE GAAP earnings						$	601								$	689

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

Earning Activities

Utility earning activities were primarily affected by the following:

• Lower operating revenue of $128 million primarily due to the following:

• During the second quarter of 2016, SCE recorded a revenue refund to customers of $133 million for 2012 – 2014 incremental tax benefits related to repair deductions, as discussed above (offset in income taxes below).

• A decrease in revenue of approximately $95 million for 2016 incremental tax benefits recognized through the tax accounting memorandum account ("TAMA") and the pole loading balancing account (offset in income taxes as discussed below). In addition, SCE recorded $26 million ($15 million after-tax) of incremental return on the pole loading rate base recorded through this balancing account. During the first six months of 2015, there was no incremental return on pole loading rate base due to the timing of the final 2015 GRC decision.

• An increase in CPUC revenue of approximately $26 million primarily due to the implementation of the 2015 GRC decision. During the first six months of 2016, SCE increased authorized revenue approximately $96 million based on the escalation mechanism set forth in the 2015 GRC decision. This increase was partially offset by approximately $70 million of the refund to customers attributable to the second quarter of 2015 as a result of the finalization of the 2015 GRC decision (see "Highlights of Operating Results" for further information).

• An increase in FERC-related revenue of $32 million primarily related to higher operating costs including amortization of the regulatory asset associated with the Coolwater-Lugo transmission project and rate base growth partially offset by a $15 million increase in 2015 revenue due to a change in estimate under the FERC formula rate mechanism.

• An increase of $15 million primarily due to tax benefits recognized in 2015 related to net operating loss carrybacks for San Onofre decommissioning costs resulting in a reduction in revenue in 2015 (offset in income taxes).

• Higher operation and maintenance expense of $17 million primarily due:

• An increase of $10 million related to transmission and distribution costs for storm-related activities.

• An increase of $10 million related to the pole loading program, which is recovered in revenue.

8

• An increase of $8 million related to a planned outage and upgrades at the Mountainview plant.

• A decrease of $11 million of lower operating costs primarily related to lower labor costs due to the workforce reductions.

• Higher depreciation, decommissioning and amortization expense of $35 million primarily related to depreciation on transmission and distribution investments and amortization of the regulatory asset related to the Coolwater-Lugo plant, as discussed above.

• Higher other income and expenses of $7 million, see "Notes to Consolidated Financial Statements—Note 14. Interest and Other Income and Other Expenses" for details.

• Lower income taxes of $94 million primarily due to lower pre-tax income and the following discrete items:

• Higher income tax benefits in 2016 primarily related to $79 million related to the flow-through of incremental tax benefits for 2012 – 2014 to customers and $56 million of repair deductions for TAMA and pole loading balancing accounts (both offset in revenue above). These items were partially offset by lower tax benefits on other property-related items in 2016.

• A change in liabilities related to uncertain tax positions related to repair deductions, which resulted in income tax benefits of $100 million during the second quarter of 2015.

Cost-Recovery Activities

Cost-recovery activities were primarily affected by the following:

• Lower operation and maintenance expense of $73 million primarily due to lower transmission access charges, lower benefit costs, and lower spending on various public purpose programs.

Supplemental Operating Revenue Information

SCE's retail billed and unbilled revenue (excluding wholesale sales and balancing account overcollections/undercollections) was $2.5 billion and $4.9 billion for the three and six months ended June 30, 2016, respectively, compared to $2.8 billion and $5.4 billion for the respective periods in 2015.

• Retail billed and unbilled revenue for the three months ended June 30, 2016 were lower compared to the same period last year primarily due to a rate decrease of $264 million. The decrease was due to implementations of the 2016 ERRA rate decrease and the 2015 GRC decision in January 2016.

• Retail billed and unbilled revenue for the six months ended June 30, 2016 reflects a rate decrease of $400 million and a sales volume decrease of $40 million. The rate decrease is primarily due to implementations of the 2016 ERRA rate decrease and the 2015 GRC decision in January 2016. The sales volume decrease is primarily due to lower load requirements related to solar generation and energy efficiency programs.

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 2015 Form 10-K).

Income Taxes

SCE's income tax provision decreased by $36 million and $94 million for the three and six months ended June 30, 2016, respectively, compared to the same periods in 2015.

The effective tax rates were (9.1)% and 1.7% for the three months ended June 30, 2016 and 2015, respectively. The effective tax rates were 3.1% and 13.4% for the six months ended June 30, 2016 and 2015, respectively. SCE's effective tax rate is lower than the statutory rate primarily due to income tax benefits related to repair deductions, mainly due to flow-through income tax benefits recorded through balancing accounts. The decrease in the effective tax rate from 2015 to 2016 is mainly due to the $133 million revenue refund to customers partially offset by the change in liabilities related to uncertain tax positions.

See "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for a reconciliation of the federal statutory rate of 35% to the effective income tax rates and "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Tax Repair Deductions and Memorandum Account" below for more information.

9

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 June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison Energy Group and subsidiaries1	$	(17	)	$	(2	)	$	(23	)	$	—
Edison Mission Group and subsidiaries	(4		)	8			(4		)	11
Corporate expenses and Other2	(16		)	(11		)	(27		)	(22		)
Total Edison International Parent and Other	$	(37	)	$	(5	)	$	(54	)	$	(11	)

¹   Includes income of $2 million and $4 million for the three and six months ended June 30, 2016, respectively, compared to income of $1 million and $6 million for the same periods in 2015 related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method.

²  Includes interest expense (pre-tax) of $9 million and $7 million for the three months ended June 30, 2016 and 2015, respectively, and $17 million and $14 million for the six months ended June 30, 2016 and 2015, respectively.

The loss from continuing operations of Edison International Parent and Other increased $32 million and $43 million for the three and six months ended June 30, 2016, respectively, compared to the same periods in 2015 primarily due to:

• An increase in losses of Edison Energy Group from a $13 million after-tax charge from a buy-out of an earn-out provision contained in one of the 2015 acquisitions, higher operating and development expenses and lower revenue and gross margin from the sale of solar systems. The buy-out was completed, together with modification to employment contracts, in order to align long-term incentive compensation. The results during the first half of 2016 include the three businesses acquired by Edison Energy in December 2015. Revenue for Edison Energy Group for the three and six months ended June 30, 2016 were $9 million and $15 million, respectively, compared to $6 million and $9 million for the respective periods in 2015.

• A decrease in income from Edison Mission Group and subsidiaries of $12 million and $15 million for the three and six months ended June 30, 2016, respectively, primarily due to income related to affordable housing projects in 2015. In December 2015, EMG's subsidiary, Edison Capital completed the sale of its remaining affordable housing investments portfolio which represents the exit from this business activity.

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.

SCE expects to fund its 2016 obligations, capital expenditures and dividends through operating cash flows, tax benefits and capital market financings of debt and preferred equity, as needed. SCE also has availability under its credit facilities to fund liquidity requirements.

Available Liquidity

At June 30, 2016, SCE had approximately $2.15 billion available under its $2.75 billion multi-year revolving credit facility. 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 June 30, 2016, SCE's debt to total capitalization ratio was 0.44 to 1.

10

Regulatory Proceedings

San Onofre CPUC Proceedings

In May 2016, and in consideration of the CPUC's December 2015 decision sanctioning SCE for failing to disclose ex parte communications relevant to the San Onofre OII, the Assigned Commissioner and ALJ issued a ruling to reopen the record upon which the CPUC had, in November 2014, approved the San Onofre OII Settlement Agreement among SCE, TURN, ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—San Onofre Related Matters—San Onofre CPUC Proceedings" for more information.

Cost of Capital

As discussed in the year-ended 2015 MD&A, SCE and the other Joint Investor-Owned Utilities submitted a petition to the CPUC in connection with their request for a one-year extension of the due date for the filing of the next cost of capital applications. A final decision approving the Joint Investor-Owned Utilities' petition was approved on February 25, 2016. As extended, the Joint Investor-Owned Utilities must file their next cost of capital applications by April 20, 2017 instead of April 20, 2016. SCE's authorized rate of return and capital structure for CPUC-related activities will remain unchanged through December 31, 2017. See "Business—SCE—Overview of Ratemaking Process—CPUC" in the 2015 Form 10-K for details on SCE's cost of capital and authorized rates of return.

Energy Efficiency Incentive Mechanism

In March 2016, ORA and TURN filed a joint proposal requesting that the CPUC recalculate SCE's 2006 – 2008 incentive awards and order SCE to refund $39.9 million to its customers. SCE disputes the assertion that SCE should be at risk to repay previously awarded incentives. SCE cannot predict the outcome of this proceeding. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Energy Efficiency Incentive Mechanism" for more information.

FERC Formula Rates

In June 2016, SCE provided its preliminary 2017 annual transmission revenue requirement update to interested parties. The update provided support for an increase in SCE's transmission revenue requirement of $98 million or 9% over amounts currently authorized in rates. The increase is mainly due to the completion of several major transmission projects and an underrecovery in rates for revenue in 2015, which is being recovered through the formula rate true up process. SCE expects to file its 2017 annual update with the FERC by December 1, 2016 and the proposed rates would be effective January 1, 2017.

Tax Repair Deductions and Memorandum Account

SCE recognized earnings and a regulatory asset for deferred income taxes related to 2012 – 2014 tax repair deductions. As a result of the CPUC's rate base offset in the 2015 GRC decision, SCE wrote down this regulatory asset in full during 2015. The after-tax charge was reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductions the CPUC used to establish the rate base offset was based on SCE's forecast of 2012 – 2014 tax repair deductions from the Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In April 2016, the CPUC granted SCE's request to reduce SCE's Base Revenue Requirement Balancing Account by $234 million during 2016 through 2020 subject to the outcome of audits that may be conducted by tax authorities. The refunds result in flowing incremental tax benefits for 2012 – 2014 to customers through 2020. SCE refunded $133 million during the second quarter of 2016. SCE did not record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings.

Capital Investment Plan

Major Transmission Projects

West of Devers

In April 2016, the CPUC issued a proposed decision to approve the project as recommended by SCE. An alternative project with a modified scope had been considered as part of required environmental impact reviews as discussed in the year-ended 2015 MD&A. The CPUC is expected to issue a final decision on the project in the third quarter of 2016.

11

Riverside Transmission Reliability

The Riverside Transmission Reliability Project is a joint project between SCE and Riverside Public Utilities (RPU), the municipal utility department of the City of Riverside. While RPU would be responsible for constructing some of the Project's facilities within Riverside, SCE's portion of the Project consists of constructing upgrades to its system, including a new 230-kV Substation; certain interconnection and telecommunication facilities and transmission lines in the cities of Riverside, Jurupa Valley and Norco and in portions of unincorporated Riverside County. The purpose of the Project is to provide RPU and its customers with adequate transmission capacity to serve existing and projected load, to provide for long-term system capacity for load growth, and to provide needed system reliability. 

Alberhill System

The Alberhill System Project consists of constructing a new 500-kV substation, two 500-kV transmission lines to connect the proposed substation to the existing Serrano-Valley 500-kV transmission line, telecommunication equipment and subtransmission lines in unincorporated and incorporated portions of western Riverside County. The Project was designed to meet long-term forecasted electrical demand in the proposed Alberhill Project area and to increase electrical system reliability.

Coolwater-Lugo

In February 2016, SCE filed an abandoned plant recovery request at FERC for the costs of the cancelled Coolwater-Lugo transmission project pursuant to the authority granted by FERC for SCE to recover 100% of all prudently-incurred costs if the project is cancelled for reasons beyond SCE's control. The project was cancelled by the CPUC in 2015 due to a reduction in need. SCE requested recovery of the $37.1 million in costs that SCE incurred for the project over a twelve-month period through the FERC transmission formula rate. In May 2016, the FERC issued an order finding that the project was cancelled for reasons beyond SCE's control, and granted SCE recovery of 100% of the prudently-incurred costs of the project, as proposed by SCE but set for hearing and settlement the $8.5 million in overhead costs assigned by SCE to the project to determine whether these costs are reasonable.

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 June 30, 2016, SCE's 13-month weighted-average common equity component of total capitalization was 50.3% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $540 million, resulting in a restriction on net assets of approximately $13.5 billion.

In the second quarter of 2016, SCE declared and paid a dividend to Edison International of $170 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.

Margin and Collateral Deposits

Certain derivative instruments, power procurement contracts and other contractual arrangements contain collateral requirements. Future collateral requirements may differ from the requirements at June 30, 2016, due to the addition of incremental power and energy procurement contracts with collateral requirements, if any, and the impact of changes in wholesale power and natural gas prices on SCE's contractual obligations.

Some of the power procurement contracts contain provisions that require SCE to maintain an investment grade credit rating from the major credit rating agencies. If SCE's credit rating were to fall below investment grade, SCE may be required to pay the liability or post additional collateral.

12

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 June 30, 2016.

(in millions)
Collateral posted as of June 30, 20161	$	91
Incremental collateral requirements for power procurement contracts resulting from a potential downgrade of SCE's credit rating to below investment grade	55
Incremental collateral requirements for power procurement contracts resulting from adverse market price movement2	6
Posted and potential collateral requirements	$	152

¹  Net collateral provided to counterparties and other brokers consisted of $95 million in letters of credit and surety bonds and $4 million of cash reflected in "Other current liabilities" on the consolidated balance sheets.

²  Incremental collateral requirements were based on potential changes in SCE's forward positions as of June 30, 2016 due to adverse market price movements over the remaining lives of the existing power procurement 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 dividends to common shareholders are dependent on dividends from SCE, realization of tax benefits and access to bank and capital markets.

At June 30, 2016, Edison International Parent had $956 million available under its $1.25 billion multi-year revolving credit facility. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."

Edison International may finance working capital requirements, payment of obligations and capital investments, including capital contributions to subsidiaries to fund new businesses, with commercial paper or other borrowings, subject to availability in the capital markets.

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 June 30, 2016, Edison International Parent's consolidated debt to total capitalization ratio was 0.47 to 1.

In August 2014, Edison International entered into an amendment of the EME Settlement Agreement that finalized the remaining matters related to the EME Settlement. Edison International is obligated to make the final payment of $214 million on September 30, 2016. Edison International has net operating loss and tax credit carryforwards retained by EME, which are available to offset future consolidated taxable income or tax liabilities. In December 2015, the PATH Act of 2015 extended 50% bonus depreciation for qualifying property retroactive to January 1, 2015 and through 2017 and provided for 40% bonus depreciation in 2018 and 30% in 2019. As a result, realization of these tax benefits has been deferred (currently forecasted through 2022). The timing of realization of these tax benefits may be further delayed in the event of future extensions of bonus depreciation and the value of the net operating loss carryforwards could be permanently reduced in the event that tax reform decreases the current corporate tax rate.

13

Historical Cash Flows

Southern California Edison Company

	Six months ended June 30,
(in millions)	2016			2015
Net cash provided by operating activities	$	1,514		$	1,689
Net cash provided by financing activities	151			539
Net cash used in investing activities	(1,671		)	(2,213		)
Net (decrease) increase in cash and cash equivalents	$	(6	)	$	15

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 six months ended June 30, 2016 and 2015.

	Six months ended June 30,						Change in cash flows
(in millions)	2016			2015			2016/2015
Net income	$	662		$	745
Non-cash items1	989			995
Subtotal	$	1,651		$	1,740		$	(89	)
Changes in cash flow resulting from working capital2	(120		)	(311		)	191
Derivative assets and liabilities, net	15			33			(18		)
Regulatory assets and liabilities, net	90			241			(151		)
Other noncurrent assets and liabilities, net3	(122		)	(14		)	(108		)
Net cash provided by operating activities	$	1,514		$	1,689		$	(175	)

¹  Non-cash items include depreciation, decommissioning and amortization, allowance for equity during construction, impairment and other charges, deferred income taxes and investment tax credits and other.

²  Changes in working capital items include receivables, inventory, accounts payable, prepaid and accrued taxes, and other current assets and liabilities.

³ Includes the nuclear decommissioning trusts.

Net cash provided by operating activities were impacted by the following:

• Net cash used for working capital was $120 million and $311 million during the six months ended June 30, 2016 and 2015, respectively. The cash outflow for each period was primarily related to the timing of receipts from customers and timing of disbursements, including payments for payroll, payroll-related costs and income taxes. During the first six months of the 2016 and 2015, SCE had net tax payments of $32 million and $125 million, respectively.

• Net cash provided by regulatory assets and liabilities, including changes in over (under) collections of balancing accounts. 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. During the first six months of 2016 and 2015, cash flows were impacted by the following principal balancing accounts:

• ERRA overcollections for fuel and purchased power decreased $187 million during the first six 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. ERRA undercollections for fuel and purchased power decreased $485 million in the first six months of 2015 primarily due to lower power and gas prices experienced in 2015.

• The base rate revenue balancing account ("BRRBA") tracks differences between amounts authorized by the CPUC in the GRC proceedings and amounts billed to customers. BRRBA overcollections increased $216 million in the first six months of 2016 primarily due to a reclassification of $206 million from TAMA to BRRBA to refund customers as required by the CPUC, partially offset by the implementation of the 2015 GRC decision in January 2016. In addition, during the second quarter of 2016, SCE recorded a revenue refund to customers of $133 million for 2012 – 2014

14

incremental tax benefits related to repair deductions. See "Liquidity and Capital Resources—Regulatory Proceedings—Tax Repair Deductions and Memorandum Account" for further information.

• The public purpose and energy efficiency programs track the differences between amounts authorized by the CPUC and amounts incurred to fund programs established by the CPUC. Overcollections increased by $145 million during the first six months of 2016 due to higher funding and lower spending for these programs. Overcollections decreased by $122 million during the first six months of 2015 due to increased spending for these programs.

• The 2015 GRC decision established the TAMA. As a result of this memorandum account, together with a balancing account for pole loading expenditures, any differences between the authorized tax repair deductions and actual tax repair deductions will be adjusted through customer rates. Overcollections decreased by $180 million during the first six months of 2016 primarily due to a $206 million reclassification from TAMA to BRRBA to refund customers as discussed above, partially offset by higher tax repairs deductions than forecasted in rates.

• SCE received $122 million in May 2016 from the federal government related to Department of Energy's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. These 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. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—Spent Nuclear Fuel" for further discussion.

• Cash flows used in other noncurrent assets and liabilities were $122 million and $14 million in the first six months of 2016 and 2015, respectively. Major factors affecting cash flow related to noncurrent assets and liabilities were activities related to SCE's nuclear decommissioning trusts (principally related to the payment of decommissioning costs). Decommissioning costs of San Onofre were approximately $88 million and $80 million for the six months ended June 30, 2016 and 2015, respectively (such costs were recorded as a reduction of SCE's asset retirement obligation).

Net Cash Provided by Financing Activities

The following table summarizes cash provided by financing activities for the six months ended June 30, 2016 and 2015. Issuances of debt and preference stock are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Long-Term Debt" and "—Note 12. Preferred and Preference Stock of SCE."

	Six months ended June 30,
(in millions)	2016			2015
Issuances of first and refunding mortgage bonds, net	$	—		$	1,287
Issuances of pollution control bonds, net	—			128
Long-term debt matured or repurchased	(41		)	(721		)
Issuances of preference stock, net	294			—
Redemptions of preference stock	(125		)	—
Short-term debt financing, net	457			184
Payments of common stock dividends to Edison International	(340		)	(294		)
Payments of preferred and preference stock dividends	(61		)	(56		)
Other	(33		)	11
Net cash provided by financing activities	$	151		$	539

Net Cash Used in Investing Activities

Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Capital expenditures were $1.8 billion and $2.2 billion for the six months ended June 30, 2016 and 2015, respectively, primarily related to transmission, distribution and generation investments. Net proceeds (purchases) of nuclear decommissioning trust investments were $144 million and $(48) million for the six months ended June 30, 2016 and 2015, respectively. The 2016 net proceeds from sale of nuclear decommissioning trust investments was due to disbursements less net earnings during the period. The 2015 net purchase of nuclear decommissioning trust investments was due to net earnings during the period.

15

Nuclear Decommissioning Trusts

SCE's statement of cash flows includes activities of the Nuclear Decommissioning Trusts, which are reflected in the following line items:

	Six months ended June 30,
(in millions)	2016			2015
Net cash (used in) provided by operating activities:    Nuclear decommissioning trusts	$	(144	)	$	41
Net cash flow from investing activities:    Proceeds from sale of investments	1,391			1,455
Purchases of investments	(1,247		)	(1,503		)
Net cash impact	$	—		$	(7	)

Net cash (used in) provided by operating activities of the nuclear decommissioning trusts relate to interest and dividends less administrative expenses, taxes and decommissioning costs. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information. Such activities represent the source (use) of the funds for investing activities. The net cash impact represents the contributions made by SCE to the nuclear decommissioning trusts.

In future periods, decommissioning costs of San Onofre will increase significantly. Beginning in March 2016, funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information.

Edison International Parent and Other

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

	Six months ended June 30,
(in millions)	2016			2015
Net cash (used in) provided by operating activities	$	(85	)	$	79
Net cash provided by (used in) financing activities	51			(66		)
Net cash used in investing activities	(10		)	(21		)
Net decrease in cash and cash equivalents	$	(44	)	$	(8	)

Net Cash (Used in) Provided by Operating Activities

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

• $122 million receipt of intercompany tax-allocation payments in 2015.

• $21 million outflow in June 2016 related to the buy-out of an earn-out provision with the former shareholders of a company acquired by Edison Energy in 2015. See "Results of Operations—Edison International Parent and Other—Income from Continuing Operations" for further information.

• approximately $64 million cash outflow from operating activities in 2016 compared to $43 million cash outflow in 2015 due to the timing of payments and receipts relating to interest and operating costs.

16

Net Cash Provided by (Used in) Financing Activities

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

	Six months ended June 30,
(in millions)	2016			2015
Dividends paid to Edison International common shareholders	$	(313	)	$	(272	)
Dividends received from SCE	340			294
Payment for stock-based compensation	(47		)	(108		)
Receipt from stock option exercises	26			63
Long-term debt issuance, net	397			—
Short-term debt financing, net	(351		)	(60		)
Other	(1		)	17
Net cash provided by (used in) financing activities	$	51		$	(66	)

Contingencies

SCE has contingencies related to San Onofre Related Matters, Energy Efficiency Incentive Mechanism,Long Beach Service Interruptions, Nuclear Insurance, Wildfire Insurance and Spent Nuclear Fuel, which are discussed in "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies."

Environmental Remediation

As of June 30, 2016, SCE had identified 19 material sites for remediation and recorded an estimated minimum liability of $130 million. SCE expects to recover 90% of its remediation costs at certain sites. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—Environmental Remediation" for further discussion.

MARKET RISK EXPOSURES

Edison International's and SCE's primary market risks are described in the 2015 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 at both June 30, 2016 and December 31, 2015. 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.

17

As of June 30, 2016, the amount of balance sheet exposure as described above broken down by the credit ratings of SCE's counterparties, was as follows:

	June 30, 2016
(in millions)	Exposure2		Collateral			Net Exposure
S&P Credit Rating1
A or higher	$	124	$	(4	)	$	120
BBB	2		—			2
Not rated	5		(14		)	—
Total	$	131	$	(18	)	$	122

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

²  Exposure excludes amounts related to contracts classified as normal purchases and sales and non-derivative contractual commitments that are not recorded on the consolidated balance sheets, except for any related net accounts receivable.

CRITICAL ACCOUNTING ESTIMATES AND POLICIES

For a complete discussion on Edison International's and SCE's critical accounting policies, see "Critical Accounting Estimates and Policies" in the year-ended 2015 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."

RISK FACTORS

The risk factors appearing in the 2015 Form 10-K under the headings set forth below are supplemented and updated as follows:

RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY

Regulatory Risks

SCE is subject to extensive regulation and the risk of adverse regulatory decisions and changes in applicable regulations or legislation.

SCE operates in a highly regulated environment. SCE's business is subject to extensive federal, state and local energy, environmental and other laws and regulations. Among other things, the CPUC regulates SCE's retail rates and capital structure, and the FERC regulates SCE's wholesale rates. The NRC regulates the decommissioning of San Onofre. The construction, planning, and siting of SCE's power plants and transmission lines in California are also subject to regulation by the CPUC.

SCE must periodically apply for licenses and permits from these various regulatory authorities and abide by their respective orders. Should SCE be unsuccessful in obtaining necessary licenses or permits or should these regulatory authorities initiate any investigations or enforcement actions or impose penalties or disallowances on SCE, SCE's business could be materially affected. The process of obtaining licenses and permits from regulatory authorities may be delayed or defeated by concerted community opposition and such delay or defeat could have a material effect on SCE's business.

In June 2016, the California Governor and state legislators announced an agreement on CPUC reform bills that, if passed, will establish rulemaking to govern communications between the CPUC officials, staff and the regulated utilities. These bills have not yet been approved by the California legislature and the particular rules they propose have yet to be adopted. Changes to the rules and processes around ex parte communications could result in delayed decisions, increased investigations, enforcement actions and penalties. In addition, the CPUC or other parties may initiate investigations of past communications between public utilities, including SCE, and CPUC officials and staff that could result in reopening completed proceedings for reconsideration.

18

In addition, existing regulations may be revised or reinterpreted and new laws and regulations may be adopted or become applicable to SCE, or its facilities or operations, in a manner that may have a detrimental effect on SCE's business or result in significant additional costs. In addition, regulations adopted via the public initiative or legislative process may apply to SCE, or its facilities or operations, in a manner that may have a detrimental effect on SCE's business or result in significant additional costs.

Competitive and Market Risks

The electricity industry is undergoing change, including increased competition, technological advancements, and political and regulatory developments

California utilities are experiencing increasing deployment of distributed energy resources, such as solar, energy storage, energy efficiency and demand response technologies. This growth will eventually require modernization of the electric distribution grid to, among other things, accommodate two-way flows of electricity and increase the grid's capacity to interconnect distributed energy resources. To this end, the CPUC is conducting proceedings to: evaluate changes to the planning and operation of the electric distribution grid in order to prepare for higher penetration of distributed energy resources; consider future grid modernization and grid reinforcement investments; evaluate if traditional grid investments can be deferred by distributed energy resources, and if feasible, what, if any, compensation would be appropriate; and clarify the role of the electric distribution grid operator. The outcome of these proceedings is unknown. These changes could materially affect SCE's business model and its financial condition and results of operations.

Customer-owned generation itself reduces the amount of electricity those customers purchase from utilities and has the effect of increasing utility rates unless customer rates are designed to allocate the costs of the distribution grid across all customers that benefit from their use. For example, customers in California that generate their own power do not currently pay all transmission and distribution charges and non-bypassable charges, subject to limitations, which result in increased utility rates for those customers who do not own their generation. Such increases influence the public discussion regarding changes in the electric utility business model.

In addition, the FERC has adopted changes that have opened transmission development to competition from independent developers, allowing such developers to compete with incumbent utilities for the construction and operation of transmission facilities. For more information, see "Business—SCE—Competition" in the 2015 Form 10-K.

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.

19

FINANCIAL STATEMENTS

Consolidated Statements of Income	Edison International
	Three months ended June 30,						Six months ended June 30,
(in millions, except per-share amounts, unaudited)	2016			2015			2016			2015
Total operating revenue	$	2,777		$	2,908		$	5,218		$	5,420
Purchased power and fuel	1,064			1,078			1,858			1,864
Operation and maintenance	721			743			1,350			1,380
Depreciation, decommissioning and amortization	505			481			982			945
Property and other taxes	85			82			178			171
Impairment and other charges	21			—			21			—
Total operating expenses	2,396			2,384			4,389			4,360
Operating income	381			524			829			1,060
Interest and other income	33			43			65			82
Interest expense	(144		)	(138		)	(284		)	(281		)
Other expenses	(11		)	(17		)	(19		)	(24		)
Income from continuing operations before income taxes	259			412			591			837
Income tax (benefit) expense	(47		)	6			(9		)	113
Income from continuing operations	306			406			600			724
Loss from discontinued operations, net of tax	(2		)	—			(1		)	—
Net income	304			406			599			724
Preferred and preference stock dividend requirements of SCE	31			28			61			56
Other noncontrolling interests	(3		)	(1		)	(8		)	(10		)
Net income attributable to Edison International common shareholders	$	276		$	379		$	546		$	678
Amounts attributable to Edison International common shareholders:
Income from continuing operations, net of tax	$	278		$	379		$	547		$	678
Loss from discontinued operations, net of tax	(2		)	—			(1		)	—
Net income attributable to Edison International common shareholders	$	276		$	379		$	546		$	678
Basic earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding	326			326			326			326
Continuing operations	$	0.86		$	1.16		$	1.68		$	2.08
Discontinued operations	(0.01		)	—			—			—
Total	$	0.85		$	1.16		$	1.68		$	2.08
Diluted earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding, including effect of dilutive securities	329			328			329			329
Continuing operations	$	0.85		$	1.15		$	1.66		$	2.06
Discontinued operations	(0.01		)	—			—			—
Total	$	0.84		$	1.15		$	1.66		$	2.06
Dividends declared per common share	$	0.4800		$	0.4175		$	0.9600		$	0.8350

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

20

Consolidated Statements of Comprehensive Income					Edison International
	Three months ended June 30,				Six months ended June 30,
(in millions, unaudited)	2016		2015		2016		2015
Net income	$	304	$	406	$	599	$	724
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Net loss arising during the period plus amortization included in net income	1		3		3		2
Other comprehensive income, net of tax	1		3		3		2
Comprehensive income	305		409		602		726
Less: Comprehensive income attributable to noncontrolling interests	28		27		53		46
Comprehensive income attributable to Edison International	$	277	$	382	$	549	$	680

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

21

Consolidated Balance Sheets	Edison International
(in millions, unaudited)	June 30, 2016		December 31, 2015
ASSETS
Cash and cash equivalents	$	111	$	161
Receivables, less allowances of $56 and $62 for uncollectible accounts at respective dates	801		771
Accrued unbilled revenue	682		565
Inventory	308		267
Derivative assets	65		79
Regulatory assets	478		560
Other current assets	214		251
Total current assets	2,659		2,654
Nuclear decommissioning trusts	4,344		4,331
Other investments	203		203
Total investments	4,547		4,534
Utility property, plant and equipment, less accumulated depreciation and amortization of $8,531 and $8,548 at respective dates	35,629		34,945
Nonutility property, plant and equipment, less accumulated depreciation of $92 and $85 at respective dates	148		140
Total property, plant and equipment	35,777		35,085
Derivative assets	69		84
Regulatory assets	7,792		7,512
Other long-term assets	353		360
Total long-term assets	8,214		7,956
Total assets	$	51,197	$	50,229

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

22

Consolidated Balance Sheets	Edison International
(in millions, except share amounts, unaudited)	June 30, 2016			December 31, 2015
LIABILITIES AND EQUITY
Short-term debt	$	800		$	695
Current portion of long-term debt	696			295
Accounts payable	1,166			1,310
Accrued taxes	74			72
Customer deposits	257			242
Derivative liabilities	195			218
Regulatory liabilities	1,072			1,128
Other current liabilities	889			967
Total current liabilities	5,149			4,927
Long-term debt	10,845			10,883
Deferred income taxes and credits	7,892			7,480
Derivative liabilities	1,101			1,100
Pensions and benefits	1,774			1,759
Asset retirement obligations	2,590			2,764
Regulatory liabilities	6,017			5,676
Other deferred credits and other long-term liabilities	2,081			2,246
Total deferred credits and other liabilities	21,455			21,025
Total liabilities	37,449			36,835
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest	—			6
Common stock, no par value (800,000,000 shares authorized; 325,811,206 shares issued and outstanding at respective dates)	2,499			2,484
Accumulated other comprehensive loss	(53		)	(56		)
Retained earnings	9,111			8,940
Total Edison International's common shareholders' equity	11,557			11,368
Noncontrolling interests – preferred and preference stock of SCE	2,191			2,020
Total equity	13,748			13,388
Total liabilities and equity	$	51,197		$	50,229

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

23

Consolidated Statements of Cash Flows	Edison International
	Six months ended June 30,
(in millions, unaudited)	2016			2015
Cash flows from operating activities:
Net income	$	599		$	724
Less: Loss from discontinued operations	(1		)	—
Income from continuing operations	600			724
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	1,025			987
Allowance for equity during construction	(42		)	(42		)
Deferred income taxes and investment tax credits	(28		)	101
Other	11			11
Nuclear decommissioning trusts	(144		)	41
EME insurance proceeds	1			—
Changes in operating assets and liabilities:
Receivables	(33		)	32
Inventory	(41		)	5
Accounts payable	67			130
Prepaid and accrued taxes	1			(50		)
Other current assets and liabilities	(135		)	(411		)
Derivative assets and liabilities, net	15			33
Regulatory assets and liabilities, net	90			241
Other noncurrent assets and liabilities	42			(34		)
Net cash provided by operating activities	1,429			1,768
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs of $3 and $16 for respective periods	397			1,415
Long-term debt matured	(41		)	(721		)
Preference stock issued, net	294			—
Preference stock redeemed	(125		)	—
Short-term debt financing, net	106			125
Dividends to noncontrolling interests	(61		)	(56		)
Dividends paid	(313		)	(272		)
Other	(55		)	(18		)
Net cash provided by financing activities	202			473
Cash flows from investing activities:
Capital expenditures	(1,828		)	(2,197		)
Proceeds from sale of nuclear decommissioning trust investments	1,391			1,455
Purchases of nuclear decommissioning trust investments	(1,247		)	(1,503		)
Other	3			11
Net cash used in investing activities	(1,681		)	(2,234		)
Net (decrease) increase in cash and cash equivalents	(50		)	7
Cash and cash equivalents at beginning of period	161			132
Cash and cash equivalents at end of period	$	111		$	139

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

24

Consolidated Statements of Income	Southern California Edison Company
	Three months ended June 30,						Six months ended June 30,
(in millions, unaudited)	2016			2015			2016			2015
Operating revenue	$	2,768		$	2,901		$	5,204		$	5,409
Purchased power and fuel	1,064			1,078			1,858			1,864
Operation and maintenance	687			724			1,290			1,346
Depreciation, decommissioning and amortization	503			481			978			943
Property and other taxes	85			82			176			170
Total operating expenses	2,339			2,365			4,302			4,323
Operating income	429			536			902			1,086
Interest and other income	33			31			65			64
Interest expense	(134		)	(131		)	(265		)	(266		)
Other expenses	(11		)	(17		)	(19		)	(24		)
Income before income taxes	317			419			683			860
Income tax (benefit) expense	(29		)	7			21			115
Net income	346			412			662			745
Less: Preferred and preference stock dividend requirements	31			28			61			56
Net income available for common stock	$	315		$	384		$	601		$	689

Consolidated Statements of Comprehensive Income
	Three months ended June 30,				Six months ended June 30,
(in millions, unaudited)	2016		2015		2016		2015
Net income	$	346	$	412	$	662	$	745
Other comprehensive income, net of tax:
Pension and postretirement benefits other than pensions:
Amortization of net loss included in net income	1		1		2		2
Other comprehensive income, net of tax	1		1		2		2
Comprehensive income	$	347	$	413	$	664	$	747

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

25

Consolidated Balance Sheets Southern California Edison Company

(in millions, unaudited)	June 30, 2016		December 31, 2015
ASSETS
Cash and cash equivalents	$	20	$	26
Receivables, less allowances of $56 and $62 for uncollectible accounts at respective dates	784		724
Accrued unbilled revenue	681		564
Inventory	254		256
Derivative assets	65		79
Regulatory assets	478		560
Other current assets	192		234
Total current assets	2,474		2,443
Nuclear decommissioning trusts	4,344		4,331
Other investments	170		168
Total investments	4,514		4,499
Utility property, plant and equipment, less accumulated depreciation and amortization of $8,531 and $8,548 at respective dates	35,629		34,945
Nonutility property, plant and equipment, less accumulated depreciation of $85 and $81 at respective dates	76		73
Total property, plant and equipment	35,705		35,018
Derivative assets	69		84
Regulatory assets	7,792		7,512
Other long-term assets	227		239
Total long-term assets	8,088		7,835
Total assets	$	50,781	$	49,795

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

26

Consolidated Balance Sheets Southern California Edison Company

(in millions, except share amounts, unaudited)	June 30, 2016			December 31, 2015
LIABILITIES AND EQUITY
Short-term debt	$	506		$	49
Current portion of long-term debt	479			79
Accounts payable	1,163			1,299
Accrued taxes	37			46
Customer deposits	257			242
Derivative liabilities	195			218
Regulatory liabilities	1,072			1,128
Other current liabilities	684			760
Total current liabilities	4,393			3,821
Long-term debt	10,024			10,460
Deferred income taxes and credits	9,509			9,073
Derivative liabilities	1,100			1,100
Pensions and benefits	1,292			1,284
Asset retirement obligations	2,588			2,762
Regulatory liabilities	6,017			5,676
Other deferred credits and other long-term liabilities	1,786			1,947
Total deferred credits and other liabilities	22,292			21,842
Total liabilities	36,709			36,123
Commitments and contingencies (Note 11)
Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and outstanding at each date)	2,168			2,168
Additional paid-in capital	656			652
Accumulated other comprehensive loss	(20		)	(22		)
Retained earnings	9,023			8,804
Total common shareholder's equity	11,827			11,602
Preferred and preference stock	2,245			2,070
Total equity	14,072			13,672
Total liabilities and equity	$	50,781		$	49,795

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

27

Consolidated Statements of Cash Flows Southern California Edison Company

	Six months ended June 30,
(in millions, unaudited)	2016			2015
Cash flows from operating activities:
Net income	$	662		$	745
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	1,017			982
Allowance for equity during construction	(42		)	(42		)
Deferred income taxes and investment tax credits	9			48
Other	5			7
Nuclear decommissioning trusts	(144		)	41
Changes in operating assets and liabilities:
Receivables	(59		)	4
Inventory	2			14
Accounts payable	73			146
Prepaid and accrued taxes	(13		)	(87		)
Other current assets and liabilities	(123		)	(388		)
Derivative assets and liabilities, net	15			33
Regulatory assets and liabilities, net	90			241
Other noncurrent assets and liabilities	22			(55		)
Net cash provided by operating activities	1,514			1,689
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs of $16 for the six months ended June 30, 2015	—			1,415
Long-term debt matured	(41		)	(721		)
Preference stock issued, net	294			—
Preference stock redeemed	(125		)	—
Short-term debt financing, net	457			184
Dividends paid	(401		)	(350		)
Other	(33		)	11
Net cash provided by financing activities	151			539
Cash flows from investing activities:
Capital expenditures	(1,822		)	(2,187		)
Proceeds from sale of nuclear decommissioning trust investments	1,391			1,455
Purchases of nuclear decommissioning trust investments	(1,247		)	(1,503		)
Other	7			22
Net cash used in investing activities	(1,671		)	(2,213		)
Net (decrease) increase in cash and cash equivalents	(6		)	15
Cash and cash equivalents, beginning of period	26			38
Cash and cash equivalents, end of period	$	20		$	53

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

28

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, a company that holds interests in subsidiaries that are engaged in competitive businesses focused on providing energy solutions to commercial and industrial customers, including distributed resources, engaging in competitive transmission opportunities, and exploring distributed water treatment and recycling. Such competitive business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutility subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements.

Edison International's and SCE's significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in the 2015 Form 10-K. This quarterly report should be read in conjunction with the financial statements and notes included in the 2015 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 of America for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three- and six-month periods ended June 30, 2016 are not necessarily indicative of the operating results for the full year.

The December 31, 2015 financial statement data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America. Certain prior year amounts have been reclassified for consistency with the current period presentation.

Cash Equivalents

Cash equivalents included 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)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Money market funds	$	36	$	37	$	4	$	8

Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows:

	Edison International				SCE
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Book balances reclassified to accounts payable	$	99	$	162	$	99	$	158

Inventory

Inventory is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being determined by the average cost method.

29

Revenue Recognition

Operating revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the

end of each reporting period. During the first six months of 2015, SCE recognized revenue from CPUC activities largely based on 2014 authorized base revenue requirements included in customer rates. In the fourth quarter of 2015, SCE implemented its 2015 GRC decision which allowed SCE to recover its revenue requirement retroactive to January 1, 2015.

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 June 30,				Six months ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	278	$	379	$	547	$	678
Participating securities dividends	—		—		—		—
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Basic earnings per share – continuing operations	$	0.86	$	1.16	$	1.68	$	2.08
Diluted earnings per share – continuing operations:
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Income impact of assumed conversions	—		—		—		—
Income from continuing operations available to common shareholders and assumed conversions	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Incremental shares from assumed conversions	3		2		3		3
Adjusted weighted average shares – diluted	329		328		329		329
Diluted earnings per share – continuing operations	$	0.85	$	1.15	$	1.66	$	2.06

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 42,890 and 1,981,596 shares of common stock for the three months ended June 30, 2016 and 2015, respectively, and 47,861 and 1,981,596 shares for the six months ended June 30, 2016 and 2015, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the exercise price of the awards was greater than the average market price of the common shares during the respective periods and, therefore, the effect would have been antidilutive.

New Accounting Guidance

Accounting Guidance Adopted

On April 7, 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At June 30, 2016, the amount of debt issuance costs that are reflected as a deduction of "Long-term debt" was $75 million for SCE and $81 million for Edison International. At December 31, 2015 the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a deduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International.

30

On April 15, 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements.

Accounting Guidance Not Yet Adopted

On May 28, 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. On July 9, 2015, the FASB approved a one-year deferral, updating the effective date to January 1, 2018.Edison International and SCE are currently evaluating this guidance and cannot determine the impact of this standard at this time. Edison International and SCE anticipates adopting the standard using the modified retrospective application which means that 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.

On January 5, 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net income. 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.

On February 25, 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 classify leases with a term of more than one year as either operating or finance leases and will need to recognize a right-of-use asset and a lease liability. 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 front-loaded expense pattern. 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. This guidance is effective January 1, 2019 but early adoption is permitted. Edison International and SCE are currently evaluating this new guidance and cannot determine the impact of this standard at this time.

On March 30, 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Under this new guidance, the tax effects related to share based payments will be recorded through the income statement. Currently, tax benefits in excess of compensation cost ("windfalls") are recorded in equity, and tax deficiencies ("shortfalls") are recorded in equity to the extent of previous windfalls, and then to the income statement. This guidance is effective January 1, 2017 but early adoption is permitted. The new standard also revised reporting on the statement of cash flows. Edison International and SCE are currently evaluating this new guidance.

On June 16, 2016, the FASB issued an accounting standards update to amend the guidance on the impairment of financial instruments. The new guidance adds an impairment model, known as the current expected credit loss model, which was based on expected losses rather than incurred losses. This guidance applies to most debt instruments, trade receivables, lease receivables, financial guarantee contracts, and loan commitments. However, available-for-sale debt securities are excluded from the model's scope. This guidance is effective on January 1, 2020, but early adoption no earlier than January 1, 2019 is permitted. Edison International and SCE are currently evaluating this new guidance.

31

Note 2.    Consolidated Statements of Changes in Equity

The following table provides Edison International's changes in equity for the six months ended June 30, 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	—		—			546			546			61			607
Other comprehensive income	—		3			—			3			—			3
Common stock dividends declared ($0.96 per share)	—		—			(313		)	(313		)	—			(313		)
Dividends to noncontrolling interests	—		—			—			—			(61		)	(61		)
Stock-based compensation	3		—			(60		)	(57		)	—			(57		)
Non-cash stock-based compensation	12		—			—			12			—			12
Issuance of preference stock	—		—			—			—			294			294
Redemption of preference stock	—		—			(2		)	(2		)	(123		)	(125		)
Balance at June 30, 2016	$	2,499	$	(53	)	$	9,111		$	11,557		$	2,191		$	13,748

The following table provides Edison International's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,445	$	(58	)	$	8,573		$	10,960		$	2,022		$	12,982
Net income	—		—			678			678			56			734
Other comprehensive loss	—		2			—			2			—			2
Common stock dividends declared ($0.835 per share)	—		—			(272		)	(272		)	—			(272		)
Dividends to noncontrolling interests	—		—			—			—			(56		)	(56		)
Stock-based compensation	15		—			(70		)	(55		)	—			(55		)
Non-cash stock-based compensation	12		—			—			12			—			12
Balance at June 30, 2015	$	2,472	$	(56	)	$	8,909		$	11,325		$	2,022		$	13,347

32

The following table provides SCE's changes in equity for the six months ended June 30, 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	—		—			—			662			—			662
Other comprehensive income	—		—			2			—			—			2
Dividends declared on common stock	—		—			—			(340		)	—			(340		)
Dividends declared on preferred and preference stock	—		—			—			(61		)	—			(61		)
Stock-based compensation	—		2			—			(40		)	—			(38		)
Non-cash stock-based compensation	—		6			—			—			—			6
Issuance of preference stock	—		(6		)	—			—			300			294
Redemption of preference stock	—		2			—			(2		)	(125		)	(125		)
Balance at June 30, 2016	$	2,168	$	656		$	(20	)	$	9,023		$	2,245		$	14,072

The following table provides SCE's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,168	$	618	$	(28	)	$	8,454		$	2,070	$	13,282
Net income	—		—		—			745			—		745
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(294		)	—		(294		)
Dividends declared on preferred and preference stock	—		—		—			(56		)	—		(56		)
Stock-based compensation	—		6		—			(23		)	—		(17		)
Non-cash stock-based compensation	—		6		—			—			—		6
Balance at June 30, 2015	$	2,168	$	630	$	(26	)	$	8,826		$	2,070	$	13,668

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 an entity that owns 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.

33

Variable Interest in VIEs that are not Consolidated

Power Purchase Contracts

SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities ("QFs") that contain variable pricing provisions based on the price of natural gas. SCE has concluded that it is not the primary beneficiary of these VIEs since it does not control the commercial and operating activities of these entities. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is the operation and maintenance of the power plants.

As of the balance sheet date, the carrying amount of assets and liabilities in SCE's consolidated balance sheet that relate to its involvement with VIEs result from amounts due under the PPAs or the fair value of those derivative contracts. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 11 of the 2015 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 4,349 MW and 4,125 MW at June 30, 2016 and 2015, respectively, and the amounts that SCE paid to these projects were $92 million and $78 million for the three months ended June 30, 2016 and 2015, respectively, and $219 million and $181 million for six months ended June 30, 2016 and 2015, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.

Unconsolidated Trusts of SCE

SCE Trust I, Trust II, Trust III, Trust IV, and Trust V were formed in 2012, 2013, 2014, 2015 and 2016, respectively, for the exclusive purpose of issuing the 5.625%, 5.10%, 5.75%, 5.375% and 5.45% trust preference securities, respectively ("trust securities"). The trusts are VIEs. SCE has concluded that it is not the primary beneficiary of these VIEs as it does not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the trusts. SCE Trust I, Trust II, Trust III, Trust IV and Trust V issued to the public trust securities in the face amounts of $475 million, $400 million, $275 million, $325 million, and $300 million respectively, (cumulative, liquidation amounts of $25 per share) and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series F, Series G, Series H, Series J, and Series K Preference Stock issued by SCE in the principal amounts of $475 million, $400 million, $275 million, $325 million and $300 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities.

The Series F, Series G, Series H, Series J and Series K Preference Stock and the corresponding trust securities do not have a maturity date. Upon any redemption of any shares of the Series F, Series G, Series H, Series J or Series K Preference Stock, a corresponding dollar amount of trust securities will be redeemed by the applicable trust (see Note 12 for further information). The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities when and if 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 and Trust IV balance sheets as of June 30, 2016 and December 31, 2015, consisted of investments of $475 million, $400 million, $275 million and $325 million in the Series F, Series G, Series H and Series J Preference Stock, respectively, $475 million, $400 million, $275 million and $325 million of trust securities, respectively, and $10,000 each of common stock. The Trust V balance sheet as of June 30, 2016 consisted of investments of $300 million in the Series K Preference Stock, $300 million of trust securities, and $10,000 of common stock.

34

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

	Three months ended June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	6	$	5	$	4	$	5	$	4
Dividend distributions	6		5		4		5		4
2015
Dividend income	$	6	$	5	$	4	*		*
Dividend distributions	6		5		4		*		*

	Six months ended June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	13	$	10	$	8	$	9	$	5
Dividend distributions	13		10		8		9		5
2015
Dividend income	$	13	$	10	$	8	*		*
Dividend distributions	13		10		8		*		*

* Not applicable.

Note 4.    Fair Value Measurements

Recurring Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (referred to as an "exit price"). Fair value of an asset or liability considers assumptions that market participants would use in pricing the asset or liability, including assumptions about nonperformance risk. As of June 30, 2016 and December 31, 2015, nonperformance risk was not material for Edison International and SCE.

Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.

Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds and money market funds.

Level 2 – Edison International 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") and long-term power agreements. Edison International Parent and Other does not have any Level 3 assets and liabilities.

Assumptions are made in order to value derivative contracts in which observable inputs are not available. Changes in fair value are based on changes to forward market prices, including extrapolation of short-term observable inputs into forecasted

35

prices for illiquid forward periods. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of fair value of derivative instruments.

SCE

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

	June 30, 2016
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	9	$	125		$	—	$	134
Other	18		—		—			—		18
Nuclear decommissioning trusts:
Stocks2	1,488		—		—			—		1,488
Fixed Income3	830		1,902		—			—		2,732
Short-term investments, primarily cash equivalents	57		117		—			—		174
Subtotal of nuclear decommissioning trusts4	2,375		2,019		—			—		4,394
Total assets	2,393		2,028		125			—		4,546
Liabilities at fair value
Derivative contracts	—		—		1,295			—		1,295
Total liabilities	—		—		1,295			—		1,295
Net assets (liabilities)	$	2,393	$	2,028	$	(1,170	)	$	—	$	3,251

	December 31, 2015
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1			Total
Assets at fair value
Derivative contracts	$	—	$	—	$	163		$	—		$	163
Other	28		—		—			—			28
Nuclear decommissioning trusts:
Stocks2	1,460		—		—			—			1,460
Fixed Income3	947		1,776		—			—			2,723
Short-term investments, primarily cash equivalents	91		81		—			—			172
Subtotal of nuclear decommissioning trusts4	2,498		1,857		—			—			4,355
Total assets	2,526		1,857		163			—			4,546
Liabilities at fair value
Derivative contracts	—		22		1,311			(15		)	1,318
Total liabilities	—		22		1,311			(15		)	1,318
Net assets (liabilities)	$	2,526	$	1,835	$	(1,148	)	$	15		$	3,228

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 71% and 70% of SCE's equity investments were located in the United States at June 30, 2016 and December 31, 2015, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $89 million and $111 million at June 30, 2016 and December 31, 2015, respectively.

⁴  Excludes net payables of $50 million and net payables of $24 million at June 30, 2016 and December 31, 2015, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

36

Edison International Parent and Other

Edison International Parent and Other assets measured at fair value consisted of money market funds of $33 million and $29 million at June 30, 2016 and December 31, 2015, respectively, classified as Level 1.

SCE Fair Value of Level 3

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Fair value of net liabilities at beginning of period	$	(1,213	)	$	(976	)	$	(1,148	)	$	(902	)
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities1	43			(68		)	(22		)	(142		)
Fair value of net liabilities at end of period	$	(1,170	)	$	(1,044	)	$	(1,170	)	$	(1,044	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	19		$	(65	)	$	(54	)	$	(148	)

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 transfers between any levels during 2016 and 2015.

Valuation Techniques Used to Determine Fair Value

The process of determining fair value is the responsibility of SCE's risk management department, which reports to SCE's chief financial officer. This department obtains observable and unobservable inputs through broker quotes, exchanges and internal valuation techniques that use both standard and proprietary models to determine fair value. Each reporting period, the risk and finance departments collaborate to determine the appropriate fair value methodologies and classifications for each derivative. Inputs are validated for reasonableness by comparison against prior prices, other broker quotes and volatility fluctuation thresholds. Inputs used and valuations are reviewed period-over-period and compared with market conditions to determine reasonableness.

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
June 30, 2016	$	119	$	—	Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
December 31, 2015	152		—		Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
Tolling
June 30, 2016	3		1,293		Option model	Volatility of gas prices	15% - 41% (20%)
						Volatility of power prices	26% - 86% (30%)
						Power prices	$25.77 - $50.38 ($37.50)
December 31, 2015	10		1,297		Option model	Volatility of gas prices	15% - 58% (20%)
						Volatility of power prices	26% - 38% (30%)
						Power prices	$24.15 - $46.93 ($34.80)

¹  Prices are in dollars per megawatt-hour.

²  Prices are in dollars per million British thermal units.

37

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:

	June 30, 2016				December 31, 2015
(in millions)	Carrying Value		Fair Value		Carrying Value		Fair Value
SCE	$	10,503	$	12,457	$	10,539	$	11,592
Edison International	11,541		13,521		11,178		12,252

The fair value of Edison International 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.

38

Note 5.    Debt and Credit Agreements

Long-Term Debt

During the first quarter of 2016, Edison International issued $400 million of 2.95% senior notes due in 2023. The proceeds from these bonds were used to repay commercial paper borrowings and for general corporate purposes.

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. In July 2016, SCE and Edison International Parent extended the maturity dates to July 2021 for $2.72 billion and $1.23 billion of these facilities, respectively. The remaining $34 million and $16 million for the SCE and Edison International Parent credit facilities, respectively, will mature in July 2020. SCE's credit facility is generally used to support commercial paper borrowings and letters of credit issued for procurement-related collateral requirements, balancing account undercollections and for general corporate purposes, including working capital requirements to support operations and capital expenditures. Edison International Parent's credit facility is used to support commercial paper borrowings and for general corporate purposes.

At June 30, 2016, SCE's outstanding commercial paper, net of discount, was $506 million at a weighted-average interest rate of 0.60%. At June 30, 2016, letters of credit issued under SCE's credit facility aggregated $89 million and are scheduled to expire in twelve months or less. At December 31, 2015, the outstanding commercial paper was $49 million at a weighted-average interest rate of 0.51%.

At June 30, 2016, Edison International Parent's outstanding commercial paper, net of discount, was $294 million at a weighted-average interest rate of 0.69%. At December 31, 2015, the outstanding commercial paper was $646 million at a weighted-average interest rate of 0.78%.

Note 6.    Derivative Instruments

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

Commodity Price Risk

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

Credit and Default Risk

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

Certain power contracts contain master netting agreements or similar agreements, which generally allow counterparties subject to the agreement to setoff amounts when certain criteria are met, such as in the event of default. The objective of netting is to reduce credit exposure. Additionally, to reduce SCE's risk exposures counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.

39

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 $24 million and $38 million as of June 30, 2016 and December 31, 2015, respectively. SCE has posted $12 million collateral at June 30, 2016 and no collateral at December 31, 2015 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 June 30, 2016, SCE would be required to post $5 million of additional collateral 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:

	June 30, 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	$	66		$	69	$	135		$	196		$	1,100	$	1,296		$	1,161
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	65		$	69	$	134		$	195		$	1,100	$	1,295		$	1,161

	December 31, 2015
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	81		$	84	$	165		$	235		$	1,100	$	1,335		$	1,170
Gross amounts offset in the consolidated balance sheets	(2		)	—		(2		)	(2		)	—		(2		)	—
Cash collateral posted1	—			—		—			(15		)	—		(15		)	(15		)
Net amounts presented in the consolidated balance sheets	$	79		$	84	$	163		$	218		$	1,100	$	1,318		$	1,155

¹  In addition, at June 30, 2016, SCE received $4 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015, SCE had posted $31 million of collateral that is not offset against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets.

Income Statement Impact of Derivative Instruments

SCE recognizes realized gains and losses on derivative instruments as purchased power expense and expects that such gains or losses will be part of the purchase power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are recorded in cash flows from operating activities in the consolidated statements of cash flows.

40

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Realized losses	$	(25	)	$	(39	)	$	(52	)	$	(75	)
Unrealized gains (losses)	72			(16		)	8			(85		)

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	June 30, 2016	December 31, 2015
Electricity options, swaps and forwards	GWh	4,980	6,221
Natural gas options, swaps and forwards	Bcf	4	32
Congestion revenue rights	GWh	80,094	109,740
Tolling arrangements	GWh	65,998	70,663

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:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Income from continuing operations before income taxes	$	259		$	412		$	591		$	837
Provision for income tax at federal statutory rate of 35%	91			144			207			293
Increase in income tax from:
State tax, net of federal benefit	4			5			11			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	2			(77		)	1			(62		)
Other	(6		)	3			(11		)	(5		)
Total income tax (benefit) expense from continuing operations	$	(47	)	$	6		$	(9	)	$	113
Effective tax rate	(18.1		)%	1.5		%	(1.5		)%	13.5		%
SCE:
Income from continuing operations before income taxes	$	317		$	419		$	683		$	860
Provision for income tax at federal statutory rate of 35%	111			147			239			301
Increase in income tax from:
State tax, net of federal benefit	6			2			15			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	(1		)	(75		)	(2		)	(65		)
Other	(7		)	2			(14		)	(8		)
Total income tax (benefit) expense from continuing operations	$	(29	)	$	7		$	21		$	115
Effective tax rate	(9.1		)%	1.7		%	3.1		%	13.4		%

¹   During the second quarter of 2016, SCE recorded $79 million for 2012 – 2014 incremental tax benefits related to repair deductions, which were flowed-through to customers ($133 million pre-tax).

41

The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates.

Repair Deductions

Previously, SCE recognized earnings and a regulatory asset for deferred income taxes related to 2012 – 2014 tax repair deductions. As a result of the CPUC's rate base offset in the 2015 GRC decision, SCE wrote down this regulatory asset in full during 2015. The after-tax charge was reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductions the CPUC used to establish the rate base offset was based on SCE's forecast of 2012 – 2014 tax repair deductions from the Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In April 2016, the CPUC granted SCE's request to reduce SCE's Base Revenue Requirement Balancing Account by $234 million during 2016 through 2020 subject to the outcome of audits that may be conducted by tax authorities. SCE refunded $133 million ($79 million after-tax) during the second quarter of 2016. The refunds result in flowing incremental tax benefits for 2012 – 2014 to customers through 2020. SCE did not record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings.

Tax Disputes

Tax Years 2007 – 2012

Edison International has reached a tentative settlement agreement with the IRS for the 2007 – 2012 tax years. The final agreement, when approved, is not expected to have a material impact on the financial statements.

During the second quarter of 2015, the Company received the IRS Revenue Agent Report for the 2010 – 2012 tax years. Edison International's and SCE's tax reserves were re-measured at that time and $94 million and $100 million, respectively, of income tax benefits were recorded in the comparable quarter for the prior year.

Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2007 – 2015 and 2003 – 2015, respectively.

Note 8.    Compensation and Benefit Plans

Pension Plans

Edison International made contributions of $47 million during the six months ended June 30, 2016, which includes contributions of $37 million by SCE. Edison International expects to make contributions of $73 million during the remainder of 2016, which includes $58 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. Annual contributions to these plans are expected to be, at a minimum, equal to the related annual expense.

42

Pension expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	39		$	35		$	78		$	70
Interest cost	44			42			88			83
Expected return on plan assets	(56		)	(57		)	(112		)	(114		)
Amortization of prior service cost	1			1			2			2
Amortization of net loss1	9			9			18			18
Expense under accounting standards	$	37		$	30		$	74		$	59
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	28		$	29		$	56		$	57
SCE:
Service cost	$	38		$	34		$	76		$	69
Interest cost	41			37			82			75
Expected return on plan assets	(53		)	(54		)	(106		)	(107		)
Amortization of prior service cost	1			2			2			3
Amortization of net loss1	8			8			16			15
Expense under accounting standards	$	35		$	27		$	70		$	55
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	26		$	26		$	52		$	53

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $1 million, respectively, for the three months ended June 30, 2016, and $6 million and $3 million, respectively, for the six months ended June 30, 2016. The amount reclassified for Edison International and SCE was $4 million and $2 million, respectively, for the three months ended June 30, 2015 and $7 million and $4 million, respectively, for the six months ended June 30, 2015.

Postretirement Benefits Other Than Pensions

Edison International made contributions of $17 million during the six months ended June 30, 2016 and expects to make contributions of $16 million during the remainder of 2016, substantially all of which are expected to be made by SCE. Annual contributions 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 benefits with respect to its employees and former employees. A participating employer may terminate the PBOP benefits with respect to its employees and former employees, as may SCE (as Plan sponsor), and, accordingly, the participants' PBOP benefits are not vested benefits.

43

PBOP expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			57
Expected return on plan assets	(28		)	(29		)	(56		)	(57		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			6			—			12
Total expense	$	7		$	14		$	14		$	30
SCE:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			56
Expected return on plan assets	(28		)	(28		)	(56		)	(56		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			5			—			11
Total expense	$	7		$	14		$	14		$	29

Workforce Reductions

SCE continues to focus on productivity improvements to mitigate rate pressure from its capital program, optimize its cost structure and improve operational efficiency, which is expected to result in further workforce reductions through 2016. During the six months ended June 30, 2016, SCE increased the estimated impact for approved workforce reductions.

The following table provides a summary of changes in the accrued severance liability associated with these reductions:

(in millions)
Balance at January 1, 2016	$	22
Additions	13
Payments	(23		)
Balance at June 30, 2016	$	12

The liability presented in the table above is reflected in "Other current liabilities" on the consolidated balance sheets. The severance costs are included in "Operation and maintenance" on the consolidated income statements.

44

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)		June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Stocks	—	$	329	$	304	$	1,488	$	1,460
Municipal bonds	2054	675		691		854		840
U.S. government and agency securities	2046	1,002		1,070		1,107		1,128
Corporate bonds	2057	683		708		771		755
Short-term investments and receivables/payables1	One-year	121		144		124		148
Total		$	2,810	$	2,917	$	4,344	$	4,331

¹ Short-term investments include $85 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and matured by July 5, 2016 and January 5, 2016 as of June 30, 2016 and December 31, 2015, respectively.

Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion and $1.4 billion at June 30, 2016 and December 31, 2015, respectively.

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Balance at beginning of period	$	4,290		$	4,896		$	4,331		$	4,799
Gross realized gains	22			5			75			32
Gross realized losses	(1		)	(3		)	(4		)	(5		)
Unrealized gains (losses), net	72			(71		)	113			(27		)
Other-than-temporary impairments	(8		)	(8		)	(33		)	(12		)
Interest and dividends	32			32			60			60
Contributions	—			—			—			7
Income taxes	(24		)	(14		)	(42		)	(14		)
Decommissioning disbursements	(38		)	—			(154		)	—
Administrative expenses and other	(1		)	(1		)	(2		)	(4		)
Balance at end of period	$	4,344		$	4,836		$	4,344		$	4,836

Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE. Deferred tax liabilities related to net unrealized gains at June 30, 2016 were $375 million. Accordingly, the fair value of Trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $4.0 billion at June 30, 2016. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.

45

Note 10.    Regulatory Assets and Liabilities

Regulatory Assets

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

(in millions)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	309	$	382
Energy derivatives	135		159
Other	34		19
Total current	478		560
Long-term:
Deferred income taxes, net	4,176		3,757
Pensions and other postretirement benefits	836		849
Energy derivatives	1,041		1,027
Unamortized investments, net	156		182
San Onofre	942		1,043
Unamortized loss on reacquired debt	193		201
Regulatory balancing accounts	49		36
Environmental remediation	128		129
Other	271		288
Total long-term	7,792		7,512
Total regulatory assets	$	8,270	$	8,072

Regulatory Liabilities

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

(in millions)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	1,050	$	1,106
Other	22		22
Total current	1,072		1,128
Long-term:
Costs of removal	2,825		2,781
Recoveries in excess of ARO liabilities1	1,740		1,502
Regulatory balancing accounts	1,392		1,314
Other	60		79
Total long-term	6,017		5,676
Total regulatory liabilities	$	7,089	$	6,804

¹ Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9.

46

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)	June 30, 2016			December 31, 2015
Asset (liability)
Energy resource recovery account	$	(252	)	$	(439	)
New system generation balancing account	(195		)	(171		)
Public purpose programs and energy efficiency programs	(828		)	(683		)
Tax accounting memorandum account and pole loading balancing account	(68		)	(248		)
Base rate recovery balancing account	(535		)	(319		)
Department of Energy litigation memorandum account1	(122		)	—
Greenhouse gas auction revenue	(4		)	(75		)
FERC balancing accounts	40			74
Other	(120		)	(141		)
Liability	$	(2,084	)	$	(2,002	)

¹ Represents a refund from the Department of Energy's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. See "Note 11. Commitments and Contingencies—Contingencies—Spent Nuclear Fuel" for further discussion.

Note 11.    Commitments and Contingencies

Indemnities

Edison International and SCE have various financial and performance guarantees and indemnity agreements, which are issued in the normal course of business.

Edison International and SCE have provided indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, and indemnities for specified environmental liabilities and income taxes with respect to assets sold. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated.

SCE has indemnified the City of Redlands, California in connection with Mountainview's California Energy Commission permit for cleanup or associated actions related to groundwater contaminated by perchlorate due to the disposal of filter cake at the City's solid waste landfill. The obligations under this agreement are not limited to a specific time period or subject to a maximum liability. SCE has not recorded a liability related to this indemnity.

Contingencies

In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business. Edison International and SCE believe the outcome of these other proceedings will not, individually or in the aggregate, materially affect its results of operations or liquidity.

San Onofre Related Matters

Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3.

47

San Onofre CPUC Proceedings

The San Onofre OII Settlement Agreement resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the related outages and subsequent shutdown of San Onofre. In May 2016, and in consideration of the CPUC's December 2015 decision sanctioning SCE for failing to disclose ex parte communications relevant to the San Onofre OII, the Assigned Commissioner and ALJ issued a ruling to reopen the record upon which the CPUC had, in November 2014, approved the San Onofre OII Settlement Agreement among SCE, TURN, ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth. The ruling also established a ban on all ex parte communications in the proceeding. The ruling established a briefing schedule for parties to address whether, in light of the ex parte rules violations, the San Onofre OII Settlement Agreement remains 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 asserts that the San Onofre OII Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of parties, however, have asked the CPUC in their comments to 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. SCE is unable to predict the outcome of this matter. The San Onofre OII Settlement Agreement does not affect proceedings related to recoveries from third parties described below, but does describe how shareholders and customers will share any recoveries.

Challenges related to San Onofre CPUC Proceedings

A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case appealed the dismissal to the Ninth Circuit in May 2015. Both the appeal and the application for rehearing remain pending.

In April 2015, the Alliance for Nuclear Responsibility ("A4NR") filed a petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement based on SCE's alleged failures to disclose communications between SCE and CPUC decision-makers pertaining to issues in the San Onofre OII. The petition seeks the reversal of the decision approving the San Onofre OII Settlement Agreement and reopening of the OII proceeding. Subsequently, TURN and ORA filed responses supporting A4NR's petition to reopen the San Onofre OII proceeding. In August 2015, ORA filed its own petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement seeking to set aside the settlement and reopen the San Onofre OII proceeding. SCE and SDG&E responded to this petition in September 2015. Both petitions remain pending before the CPUC.

In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief Executive Officer and Chief Financial Officer and was later amended to include SCE's former President as a defendant. The lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than initially reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International common stock between March 21, 2014 and June 24, 2015.

Subsequently and also in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same allegations was filed in August and was subsequently consolidated with the July 2015 federal derivative lawsuit.

In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the federal derivative lawsuits discussed above.

In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief Executive Officer and Treasurer by an Edison International employee, alleging claims under the Employee Retirement Income Security Act ("ERISA"). The complaint purports to be filed on behalf of a class of Edison International employees who were participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between March 27, 2014 and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew or should have known that investment in the Edison International Stock Fund was imprudent because the price of Edison International common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte communications with CPUC decision-makers related to the San Onofre OII. In July 2016, the federal court granted the defendants' motion to dismiss the lawsuit with an opportunity for the plaintiffs to amend their complaint.

48

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

MHI Claims

SCE is also pursuing claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"), which designed and supplied the replacement steam generators. MHI warranted the replacement steam generators for an initial period of 20 years from acceptance and is contractually obligated to repair or replace defective items with dispatch and to pay specified damages for certain repairs. MHI's stated liability under the purchase agreement is limited to $138 million and excludes consequential damages, defined to include "the cost of replacement power;" however, limitations in the contract are subject to applicable exceptions both in the contract and under law. SCE has advised MHI that it believes one or more of such exceptions apply and that MHI's liability is not limited to $138 million. MHI has advised SCE that it disagrees. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce in accordance with the purchase contract seeking damages for all losses. In the request for arbitration, SCE alleges contract and tort claims and seeks at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI has denied any liability and has asserted counterclaims for $41 million, for which SCE has denied any liability. Each of the other San Onofre owners sued MHI, alleging claims arising from MHI's supplying the faulty steam generators. These litigation claims have been stayed pending the arbitration. The other co-owners (SDG&E and Riverside) have been added as additional claimants in the arbitration. The arbitration is being conducted pursuant to a confidentiality order issued by the arbitration panel. Hearings concluded on April 29, 2016. A decision may be issued by year-end 2016 but could be later.

SCE, on behalf of itself and the other San Onofre co-owners, has submitted seven invoices to MHI totaling $149 million for steam generator repair costs incurred through April 30, 2013. MHI paid the first invoice of $45 million, while reserving its right to challenge it and subsequently rejected a portion of the first invoice and has not paid further invoices, claiming further documentation is required, which SCE disputes. SCE recorded its share of the invoice paid (approximately $35 million) as a reduction of repair and inspection costs in 2012.

Under the San Onofre OII Settlement Agreement, recoveries from MHI (including amounts paid by MHI under the first invoice), if any, will first be applied to reimburse costs incurred in pursuing such recoveries, including litigation costs. To the extent SCE's share of recoveries from MHI exceed such costs, they will be allocated 50% to customers and 50% to SCE.

The first $282 million of SCE's customers' portion of such recoveries from MHI will be distributed to customers via a credit to a sub-account of SCE's Base Revenue Requirement Balancing Account ("BRRBA"), reducing revenue requirements from customers. Amounts in excess of the first $282 million distributable to SCE customers will reduce SCE's regulatory asset represented by the unamortized balance of investment in San Onofre base plant, reducing the revenue requirement needed to amortize such investment. The amortization period, however, will be unaffected. Any additional amounts received after the regulatory asset is recovered will be applied to the BRRBA.

The San Onofre OII Settlement Agreement provides the utilities with the discretion to resolve the MHI dispute without CPUC approval, but the utilities are obligated to use their best efforts to inform the CPUC of any settlement or other resolution of these disputes to the extent this is possible without compromising any aspect of the resolution. SCE and SDG&E have also agreed to allow the CPUC to review the documentation of any final resolution of the MHI dispute and the litigation costs incurred in pursuing claims against MHI to ensure they are not exorbitant in relation to the recovery obtained. There is no assurance that there will be any recovery from MHI or, if there is a recovery, that it will equal or exceed the litigation costs incurred to pursue the recovery.

Energy Efficiency Incentive Mechanism

In September 2015, the CPUC granted TURN and ORA requests for rehearing of prior CPUC decisions related to $74.5 million of incentive awards that SCE received for savings achieved by its 2006 – 2008 energy efficiency programs. In March 2016, ORA and TURN filed a joint proposal requesting that the CPUC recalculate SCE's 2006 – 2008 incentive awards and order SCE to refund $39.9 million to its customers. SCE disputes the assertion that SCE should be at risk to repay previously awarded incentives. SCE cannot predict the outcome of these petitions.

Long Beach Service Interruptions

In July 2015, SCE's customers who are served via the network portion of SCE's electric system in Long Beach, California experienced service interruptions due to multiple underground vault fires and underground cable failures. No personal injuries have been reported in connection with these events and, subject to applicable deductibles, SCE is generally insured against customer claims arising from these events. SCE instituted an internal investigation and commissioned an external

49

investigation of these events and their causes, which revealed that the main cause of the interruptions was a lack of adequate management oversight of the downtown network system. The investigations also revealed deficiencies in maintaining the knowledge base on the configuration and operation of the system, and a lack of sophisticated controls needed to more efficiently and effectively prevent and respond to the cascading events that occurred. On July 14, 2016, the CPUC initiated an investigation ("Long Beach OII") of these events and their causes based on an investigation by the CPUC's Safety and Enforcement Division ("SED"). The SED investigation, among other things, identified problems with maintenance, inspection, and management of SCE's Long Beach electrical system, and emergency response and communications capabilities. The Long Beach OII will consider whether SCE violated statutes, rules or regulations, maintained adequate, accurate, and complete records, and provided sufficient emergency response and communications to various parties during the power outages. SCE has been directed to show cause at hearings why the CPUC should not find it in violation of the relevant statutes, rules and regulations. The OII does not propose a penalty amount. The CPUC may impose penalties in the amount of $500 to $50,000 per day per violation, but SCE is unable to estimate a possible loss or range of loss associated with any penalties that may be imposed by the CPUC in the Long Beach OII.

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 June 30, 2016, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites in which the upper end of the range of the costs is at least $1 million) was $130 million, including $79 million related to San Onofre. In addition to these sites, SCE also has 39 immaterial sites for which the total minimum recorded liability was $4 million. Of the $134 million total environmental remediation liability for SCE, $128 million has been recorded as a regulatory asset. SCE expects to recover $46 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $82 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.

The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $165 million and $7 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.

SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next four years are expected to range from $7 million to $23 million. Costs incurred for the six months ended June 30, 2016 and 2015 were $1 million and $3 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.

50

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 2015 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. Prolonged drought conditions in California have also increased the duration of the wildfire season and the risk of severe wildfire events. SCE has approximately $910 million of third party insurance coverage for wildfire liabilities for the period from July 2016 to May 2017. SCE's program includes approximately $90 million in self-insurance at various levels within the $910 million of third party insurance coverage, which combined, equals approximately $1 billion. In addition, SCE has a self-insured retention of $10 million per wildfire occurrence. SCE may experience coverage reductions and/or increased insurance costs in future years. No assurance can be given that future losses will not exceed the limits of SCE's insurance coverage.

Spent Nuclear Fuel

Under federal law, the Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept 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. All damages recovered by SCE are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs.

Note 12.    Preferred and Preference Stock of SCE

During the first quarter of 2016, SCE issued $300 million of 5.45% Series K Preference Stock (120,004 shares; cumulative, $2,500 liquidation value) to SCE Trust V, a special purpose entity formed to issue trust securities as discussed in Note 3. The Series K Preference Stock may be redeemed at par, in whole, but not in part, at any time prior to March 15, 2026 if certain changes in tax or investment company laws occur. On or after March 15, 2026, SCE may redeem the Series K shares at par, in whole or in part and distributions will accrue and be payable at a floating rate. The shares are not subject to mandatory redemption. The proceeds were used to redeem $125 million of SCE's Series D Preference Stock and for general corporate purposes.

51

Note 13.    Accumulated Other Comprehensive Loss

Edison International's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(54	)	$	(59	)	$	(56	)	$	(58	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(4		)
Reclassified from accumulated other comprehensive loss1	1			4			3			6
Change	1			3			3			2
Ending Balance	$	(53	)	$	(56	)	$	(53	)	$	(56	)

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

SCE's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(21	)	$	(27	)	$	(22	)	$	(28	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(1		)
Reclassified from accumulated other comprehensive loss1	1			2			2			3
Change	1			1			2			2
Ending Balance	$	(20	)	$	(26	)	$	(20	)	$	(26	)

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

Note 14.    Interest and Other Income and Other Expenses

Interest and other income and other expenses are as follows:

	Three months ended June 30,				Six months ended June 30,
(in millions)	2016		2015		2016		2015
SCE interest and other income:
Equity allowance for funds used during construction	$	19	$	21	$	42	$	42
Increase in cash surrender value of life insurance policies and life insurance benefits	11		7		17		17
Interest income	2		2		3		3
Other	1		1		3		2
Total SCE interest and other income	33		31		65		64
Other income of Edison International Parent and Other1	—		12		—		18
Total Edison International interest and other income	$	33	$	43	$	65	$	82
SCE other expenses:
Civic, political and related activities and donations	8		9		$	12	$	14
Other	3		8		7		10
Total SCE other expenses	11		17		19		24
Total Edison International other expenses	$	11	$	17	$	19	$	24

¹  Reflects Edison Capital's income related to the sale of affordable housing projects for the three and six months ended June 30, 2015.

52

Note 15.    Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International					SCE
	Six months ended June 30,
(in millions)	2016		2015			2016		2015
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	228	$	230		$	221	$	222
Tax payments, net	12		3			32		125
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	156	$	136		$	—	$	147
Preferred and preference stock	12		18			12		18
Details of debt exchange:
Pollution-control bonds redeemed (2.875%)	$	—	$	(203	)	$	—	$	(203	)
Pollution-control bonds issued (1.875%)	—		203			—		203

SCE's accrued capital expenditures at June 30, 2016 and 2015 were $338 million and $393 million, respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid.

During the second quarter of 2015, SCE amended a power contract classified as a capital lease, which resulted in a reduction in the lease obligation and asset by $147 million.

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 second quarter of 2016. 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.

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 second quarter of 2016 that have materially affected, or are reasonably likely to materially affect, Edison International's or SCE's internal control over financial reporting.

Jointly Owned Plant

Edison International's and SCE's respective scope of evaluation of internal control over financial reporting includes their Jointly Owned SCE Projects as discussed in Note 2. Property, Plant and Equipment in the 2015 Form 10-K.

LEGAL PROCEEDINGS

The following proceeding was previously reported to comply with SEC regulations, which require disclosure of certain information about proceedings arising under federal, state or local environmental provisions if a company reasonably believes that such proceedings might result in monetary sanctions of $100,000 or more.

Shaver Lake Dam Project Administrative Civil Liability Complaint

In 2011, SCE installed a PVC plastic geomembrane liner on the Shaver Lake Dam to prevent water seepage. Before starting the project, SCE received the required regulatory permits and approvals. SCE and the California Department of Fish and Wildlife executed a Streambed Alteration Agreement in November 2011 that governed SCE's activities in Shaver Lake as required by state and federal law. SCE also obtained the required federal Clean Water Act Certification in November 2011 for the project's completion.

53

In February 2012, the California Department of Fish and Wildlife and the Central Valley Regional Water Quality control Board issued letters alleging that SCE had violated provisions of the Streambed Alteration Agreement and certain conditions of the federal Clean Water Act Certification, respectively. Both letters alleged that during the draining of Shaver Lake, SCE failed to prevent the discharge of sediment into an adjoining creek, causing the deaths of fish in the lake and creek. In October 2014, SCE received a pre-issuance draft of an Administrative Civil Liability Complaint from the Central Valley Regional Water Quality Control Board alleging violations of certain permit conditions relating to the Shaver Lake Dam Project. The Regional Water Quality Control Board is seeking $25 million in civil penalties for the violations. SCE disputes the allegations but is working with the regulatory agencies to resolve the matter.

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 second quarter of 2016.

Period	(a) Total Number of Shares (or Units) Purchased1	(b) Average Price Paid per Share (or Unit)1			(c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs	(d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
April 1, 2016 to April 30, 2016	175,895		$	69.79	—	—
May 1, 2016 to May 31, 2016	311,408		70.99		—	—
June 1, 2016 to June 30, 2016	244,477		75.44		—	—
Total	731,780		$	72.19	—	—

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.

54

EXHIBITS

Exhibit Number	Description
3.1	Edison International Bylaws, as amended effective September 30, 2016 (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 8-K dated May 25, 2016 and filed May 25, 2016)*
3.2	Southern California Edison Company Bylaws, as amended effective June 1, 2016 (File No. 1-2313, filed as Exhibit 3.2 to Southern California Edison Company's Form 8-K dated May 25, 2016 and filed May 25, 2016)*
10.1**	Edison International 2007 Performance Incentive Plan, as amended and restated effective May 2, 2016 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated April 28, 2016 and filed April 29, 2016)
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 June 30, 2016, filed on July 28, 2016, formatted in XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; 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 June 30, 2016, filed on July 28, 2016, formatted in XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; and (v) the Notes to Consolidated Financial Statements

________________________________________

* Incorporated by reference pursuant to Rule 12b-32.

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

55

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:	July 28, 2016	Date:	July 28, 2016

56

EX-31.1

Exhibit 31.1

CERTIFICATION

I, THEODORE F. CRAVER, JR., certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, 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: July 28, 2016

/s/ THEODORE F. CRAVER, JR.

THEODORE F. CRAVER, JR.

Chief Executive Officer

Exhibit 31.1

CERTIFICATION

I, W. JAMES SCILACCI, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, 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: July 28, 2016

/s/ W. JAMES SCILACCI

W. JAMES SCILACCI

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 June 30, 2016, 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: July 28, 2016

/s/ KEVIN M. PAYNE

KEVIN M. PAYNE

Chief Executive Officer

Exhibit 31.2

CERTIFICATION

I, MARIA RIGATTI, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, 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: July 28, 2016

/s/ MARIA RIGATTI

MARIA RIGATTI

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 June 30, 2016 (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 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: July 28, 2016

/s/ THEODORE F. CRAVER, JR.

THEODORE F. CRAVER, JR.

Chief Executive Officer

Edison International

/s/ W. JAMES SCILACCI

W. JAMES SCILACCI

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 June 30, 2016 (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 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: July 28, 2016

/s/ KEVIN M. PAYNE

KEVIN M. PAYNE

Chief Executive Officer

Southern California Edison Company

/s/ MARIA RIGATTI

MARIA RIGATTI

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	6 Months Ended
	Jun. 30, 2016	Jul. 26, 2016
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	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
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	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Total operating revenue	$ 2,777	$ 2,908	$ 5,218	$ 5,420
Purchased power and fuel	1,064	1,078	1,858	1,864
Operation and maintenance	721	743	1,350	1,380
Depreciation, decommissioning and amortization	505	481	982	945
Property and other taxes	85	82	178	171
Impairment and other charges	21	0	21	0
Total operating expenses	2,396	2,384	4,389	4,360
Operating income	381	524	829	1,060
Interest and other income	33	43	65	82
Interest expense	(144)	(138)	(284)	(281)
Other expenses	(11)	(17)	(19)	(24)
Income from continuing operations before income taxes	259	412	591	837
Income tax (benefit) expense	(47)	6	(9)	113
Income from continuing operations	306	406	600	724
Less: loss from discontinued operations	(2)	0	(1)	0
Net income	304	406	599	724
Preferred and preference stock dividend requirements of SCE	31	28	61	56
Other noncontrolling interests	(3)	(1)	(8)	(10)
Net income attributable to common shareholders	276	379	546	678
Amounts attributable to Edison International common shareholders:
Income from continuing operations, net of tax	278	379	547	678
Loss from discontinued operations, net of tax	(2)	0	(1)	0
Net income attributable to common shareholders	$ 276	$ 379	$ 546	$ 678
Basic earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding (in shares)	326	326	326	326
Continuing operations (in dollars per share)	$ 0.86	$ 1.16	$ 1.68	$ 2.08
Discontinued operations (in dollars per share)	(0.01)	0.00	0.00	0.00
Total (in dollars per share)	$ 0.85	$ 1.16	$ 1.68	$ 2.08
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	328	329	329
Continuing operations (in dollars per share)	$ 0.85	$ 1.15	$ 1.66	$ 2.06
Discontinued operations (in dollars per share)	(0.01)	0.00	0.00	0.00
Total (in dollars per share)	0.84	1.15	1.66	2.06
Dividends declared per common share (in dollars per share)	$ 0.4800	$ 0.4175	$ 0.96	$ 0.8350
Southern California Edison
Total operating revenue	$ 2,768	$ 2,901	$ 5,204	$ 5,409
Purchased power and fuel	1,064	1,078	1,858	1,864
Operation and maintenance	687	724	1,290	1,346
Depreciation, decommissioning and amortization	503	481	978	943
Property and other taxes	85	82	176	170
Total operating expenses	2,339	2,365	4,302	4,323
Operating income	429	536	902	1,086
Interest and other income	33	31	65	64
Interest expense	(134)	(131)	(265)	(266)
Other expenses	(11)	(17)	(19)	(24)
Income from continuing operations before income taxes	317	419	683	860
Income tax (benefit) expense	(29)	7	21	115
Net income	346	412	662	745
Preferred and preference stock dividend requirements of SCE	31	28	61	56
Net income attributable to common shareholders	315	384	601	689
Amounts attributable to Edison International common shareholders:
Net income attributable to common shareholders	$ 315	$ 384	$ 601	$ 689

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net income	$ 304	$ 406	$ 599	$ 724
Pension and postretirement benefits other than pensions:
Net loss arising during the period plus amortization included in net income	1	3	3	2
Other comprehensive income, net of tax	1	3	3	2
Comprehensive income	305	409	602	726
Less: Comprehensive income attributable to noncontrolling interests	28	27	53	46
Comprehensive income attributable to Edison International	277	382	549	680
Southern California Edison
Net income	346	412	662	745
Pension and postretirement benefits other than pensions:
Net loss arising during the period plus amortization included in net income	1	1	2	2
Other comprehensive income, net of tax	1	1	2	2
Comprehensive income	$ 347	$ 413	$ 664	$ 747

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 111	$ 161
Receivables, less allowances for uncollectible accounts	801	771
Accrued unbilled revenue	682	565
Inventory	308	267
Derivative assets	65	79
Regulatory assets	478	560
Other current assets	214	251
Total current assets	2,659	2,654
Nuclear decommissioning trusts	4,344	4,331
Other investments	203	203
Total investments	4,547	4,534
Utility property, plant and equipment, less accumulated depreciation and amortization	35,629	34,945
Nonutility property, plant and equipment, less accumulated depreciation	148	140
Total property, plant and equipment	35,777	35,085
Derivative assets	69	84
Regulatory assets	7,792	7,512
Other long-term assets	353	360
Total long-term assets	8,214	7,956
Total assets	51,197	50,229
LIABILITIES AND EQUITY
Short-term debt	800	695
Current portion of long-term debt	696	295
Accounts payable	1,166	1,310
Accrued taxes	74	72
Customer deposits	257	242
Derivative liabilities	195	218
Regulatory liabilities	1,072	1,128
Other current liabilities	889	967
Total current liabilities	5,149	4,927
Long-term debt	10,845	10,883
Deferred income taxes and credits	7,892	7,480
Derivative liabilities	1,101	1,100
Pensions and benefits	1,774	1,759
Asset retirement obligations	2,590	2,764
Regulatory liabilities	6,017	5,676
Other deferred credits and other long-term liabilities	2,081	2,246
Total deferred credits and other liabilities	21,455	21,025
Total liabilities	37,449	36,835
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest	0	6
Common stock, no par value	2,499	2,484
Accumulated other comprehensive loss	(53)	(56)
Retained earnings	9,111	8,940
Total common shareholders' equity	11,557	11,368
Noncontrolling interests – preferred and preference stock of SCE	2,191	2,020
Total equity	13,748	13,388
Total liabilities and equity	51,197	50,229
Southern California Edison
ASSETS
Cash and cash equivalents	20	26
Receivables, less allowances for uncollectible accounts	784	724
Accrued unbilled revenue	681	564
Inventory	254	256
Derivative assets	65	79
Regulatory assets	478	560
Other current assets	192	234
Total current assets	2,474	2,443
Nuclear decommissioning trusts	4,344	4,331
Other investments	170	168
Total investments	4,514	4,499
Utility property, plant and equipment, less accumulated depreciation and amortization	35,629	34,945
Nonutility property, plant and equipment, less accumulated depreciation	76	73
Total property, plant and equipment	35,705	35,018
Derivative assets	69	84
Regulatory assets	7,792	7,512
Other long-term assets	227	239
Total long-term assets	8,088	7,835
Total assets	50,781	49,795
LIABILITIES AND EQUITY
Short-term debt	506	49
Current portion of long-term debt	479	79
Accounts payable	1,163	1,299
Accrued taxes	37	46
Customer deposits	257	242
Derivative liabilities	195	218
Regulatory liabilities	1,072	1,128
Other current liabilities	684	760
Total current liabilities	4,393	3,821
Long-term debt	10,024	10,460
Deferred income taxes and credits	9,509	9,073
Derivative liabilities	1,100	1,100
Pensions and benefits	1,292	1,284
Asset retirement obligations	2,588	2,762
Regulatory liabilities	6,017	5,676
Other deferred credits and other long-term liabilities	1,786	1,947
Total deferred credits and other liabilities	22,292	21,842
Total liabilities	36,709	36,123
Commitments and contingencies (Note 11)
Common stock, no par value	2,168	2,168
Additional paid-in capital	656	652
Accumulated other comprehensive loss	(20)	(22)
Retained earnings	9,023	8,804
Total common shareholders' equity	11,827	11,602
Noncontrolling interests – preferred and preference stock of SCE	2,245	2,070
Total equity	14,072	13,672
Total liabilities and equity	$ 50,781	$ 49,795

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Receivables, allowances for uncollectible accounts	$ 56	$ 62
Utility property, plant and equipment, accumulated depreciation	8,531	8,548
Nonutility property, plant and equipment, accumulated depreciation	$ 92	$ 85
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
Receivables, allowances for uncollectible accounts	$ 56	$ 62
Utility property, plant and equipment, accumulated depreciation	8,531	8,548
Nonutility property, plant and equipment, accumulated depreciation	$ 85	$ 81
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	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net income	$ 599	$ 724
Less: loss from discontinued operations	(1)	0
Income from continuing operations	600	724
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	1,025	987
Allowance for equity during construction	(42)	(42)
Deferred income taxes and investment tax credits	(28)	101
Other	11	11
Nuclear decommissioning trusts	(144)	41
EME insurance proceeds	1	0
Changes in operating assets and liabilities:
Receivables	(33)	32
Inventory	(41)	5
Accounts payable	67	130
Prepaid and accrued taxes	1	(50)
Other current assets and liabilities	(135)	(411)
Derivative assets and liabilities, net	15	33
Regulatory assets and liabilities, net	90	241
Other noncurrent assets and liabilities	42	(34)
Net cash provided by operating activities	1,429	1,768
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs	397	1,415
Long-term debt matured	(41)	(721)
Preference stock issued, net	294	0
Preference stock redeemed	(125)	0
Short-term debt financing, net	106	125
Dividends to noncontrolling interests	(61)	(56)
Dividends paid	(313)	(272)
Other	(55)	(18)
Net cash provided by financing activities	202	473
Cash flows from investing activities:
Capital expenditures	(1,828)	(2,197)
Proceeds from sale of nuclear decommissioning trust investments	1,391	1,455
Purchases of nuclear decommissioning trust investments	(1,247)	(1,503)
Other	3	11
Net cash used in investing activities	(1,681)	(2,234)
Net (decrease) increase in cash and cash equivalents	(50)	7
Cash and cash equivalents at beginning of period	161	132
Cash and cash equivalents at end of period	111	139
Southern California Edison
Cash flows from operating activities:
Net income	662	745
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	1,017	982
Allowance for equity during construction	(42)	(42)
Deferred income taxes and investment tax credits	9	48
Other	5	7
Nuclear decommissioning trusts	(144)	41
Changes in operating assets and liabilities:
Receivables	(59)	4
Inventory	2	14
Accounts payable	73	146
Prepaid and accrued taxes	(13)	(87)
Other current assets and liabilities	(123)	(388)
Derivative assets and liabilities, net	15	33
Regulatory assets and liabilities, net	90	241
Other noncurrent assets and liabilities	22	(55)
Net cash provided by operating activities	1,514	1,689
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs	0	1,415
Long-term debt matured	(41)	(721)
Preference stock issued, net	294	0
Preference stock redeemed	(125)	0
Short-term debt financing, net	457	184
Dividends paid	(401)	(350)
Other	(33)	11
Net cash provided by financing activities	151	539
Cash flows from investing activities:
Capital expenditures	(1,822)	(2,187)
Proceeds from sale of nuclear decommissioning trust investments	1,391	1,455
Purchases of nuclear decommissioning trust investments	(1,247)	(1,503)
Other	7	22
Net cash used in investing activities	(1,671)	(2,213)
Net (decrease) increase in cash and cash equivalents	(6)	15
Cash and cash equivalents at beginning of period	26	38
Cash and cash equivalents at end of period	$ 20	$ 53

XML

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Discounts and issuance costs of long term debt	$ 3	$ 16
Southern California Edison
Discounts and issuance costs of long term debt		$ 16

XML

Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

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, a company that holds interests in subsidiaries that are engaged in competitive businesses focused on providing energy solutions to commercial and industrial customers, including distributed resources, engaging in competitive transmission opportunities, and exploring distributed water treatment and recycling. Such competitive business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutility subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements.

Edison International's and SCE's significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in the 2015 Form 10-K. This quarterly report should be read in conjunction with the financial statements and notes included in the 2015 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 of America for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three- and six-month periods ended June 30, 2016 are not necessarily indicative of the operating results for the full year.

The December 31, 2015 financial statement data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America. Certain prior year amounts have been reclassified for consistency with the current period presentation.

Cash Equivalents

Cash equivalents included 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)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Money market funds	$	36	$	37	$	4	$	8

Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows:

	Edison International				SCE
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Book balances reclassified to accounts payable	$	99	$	162	$	99	$	158

Inventory

Inventory is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being determined by the average cost method.

Revenue Recognition

Operating revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the

end of each reporting period. During the first six months of 2015, SCE recognized revenue from CPUC activities largely based on 2014 authorized base revenue requirements included in customer rates. In the fourth quarter of 2015, SCE implemented its 2015 GRC decision which allowed SCE to recover its revenue requirement retroactive to January 1, 2015.

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 June 30,				Six months ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	278	$	379	$	547	$	678
Participating securities dividends	—		—		—		—
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Basic earnings per share – continuing operations	$	0.86	$	1.16	$	1.68	$	2.08
Diluted earnings per share – continuing operations:
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Income impact of assumed conversions	—		—		—		—
Income from continuing operations available to common shareholders and assumed conversions	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Incremental shares from assumed conversions	3		2		3		3
Adjusted weighted average shares – diluted	329		328		329		329
Diluted earnings per share – continuing operations	$	0.85	$	1.15	$	1.66	$	2.06

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 42,890 and 1,981,596 shares of common stock for the three months ended June 30, 2016 and 2015, respectively, and 47,861 and 1,981,596 shares for the six months ended June 30, 2016 and 2015, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the exercise price of the awards was greater than the average market price of the common shares during the respective periods and, therefore, the effect would have been antidilutive.

New Accounting Guidance

Accounting Guidance Adopted

On April 7, 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At June 30, 2016, the amount of debt issuance costs that are reflected as a deduction of "Long-term debt" was $75 million for SCE and $81 million for Edison International. At December 31, 2015 the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a deduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International.

On April 15, 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements.

Accounting Guidance Not Yet Adopted

On May 28, 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. On July 9, 2015, the FASB approved a one-year deferral, updating the effective date to January 1, 2018.Edison International and SCE are currently evaluating this guidance and cannot determine the impact of this standard at this time. Edison International and SCE anticipates adopting the standard using the modified retrospective application which means that 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.

On January 5, 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net income. 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.

On February 25, 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 classify leases with a term of more than one year as either operating or finance leases and will need to recognize a right-of-use asset and a lease liability. 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 front-loaded expense pattern. 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. This guidance is effective January 1, 2019 but early adoption is permitted. Edison International and SCE are currently evaluating this new guidance and cannot determine the impact of this standard at this time.

On March 30, 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Under this new guidance, the tax effects related to share based payments will be recorded through the income statement. Currently, tax benefits in excess of compensation cost ("windfalls") are recorded in equity, and tax deficiencies ("shortfalls") are recorded in equity to the extent of previous windfalls, and then to the income statement. This guidance is effective January 1, 2017 but early adoption is permitted. The new standard also revised reporting on the statement of cash flows. Edison International and SCE are currently evaluating this new guidance.

On June 16, 2016, the FASB issued an accounting standards update to amend the guidance on the impairment of financial instruments. The new guidance adds an impairment model, known as the current expected credit loss model, which was based on expected losses rather than incurred losses. This guidance applies to most debt instruments, trade receivables, lease receivables, financial guarantee contracts, and loan commitments. However, available-for-sale debt securities are excluded from the model's scope. This guidance is effective on January 1, 2020, but early adoption no earlier than January 1, 2019 is permitted. Edison International and SCE are currently evaluating this new guidance.

XML

Consolidated Statements of Changes in Equity

6 Months Ended

Jun. 30, 2016

Statement of Stockholders' 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 six months ended June 30, 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	—		—			546			546			61			607
Other comprehensive income	—		3			—			3			—			3
Common stock dividends declared ($0.96 per share)	—		—			(313		)	(313		)	—			(313		)
Dividends to noncontrolling interests	—		—			—			—			(61		)	(61		)
Stock-based compensation	3		—			(60		)	(57		)	—			(57		)
Non-cash stock-based compensation	12		—			—			12			—			12
Issuance of preference stock	—		—			—			—			294			294
Redemption of preference stock	—		—			(2		)	(2		)	(123		)	(125		)
Balance at June 30, 2016	$	2,499	$	(53	)	$	9,111		$	11,557		$	2,191		$	13,748

The following table provides Edison International's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,445	$	(58	)	$	8,573		$	10,960		$	2,022		$	12,982
Net income	—		—			678			678			56			734
Other comprehensive loss	—		2			—			2			—			2
Common stock dividends declared ($0.835 per share)	—		—			(272		)	(272		)	—			(272		)
Dividends to noncontrolling interests	—		—			—			—			(56		)	(56		)
Stock-based compensation	15		—			(70		)	(55		)	—			(55		)
Non-cash stock-based compensation	12		—			—			12			—			12
Balance at June 30, 2015	$	2,472	$	(56	)	$	8,909		$	11,325		$	2,022		$	13,347

The following table provides SCE's changes in equity for the six months ended June 30, 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	—		—			—			662			—			662
Other comprehensive income	—		—			2			—			—			2
Dividends declared on common stock	—		—			—			(340		)	—			(340		)
Dividends declared on preferred and preference stock	—		—			—			(61		)	—			(61		)
Stock-based compensation	—		2			—			(40		)	—			(38		)
Non-cash stock-based compensation	—		6			—			—			—			6
Issuance of preference stock	—		(6		)	—			—			300			294
Redemption of preference stock	—		2			—			(2		)	(125		)	(125		)
Balance at June 30, 2016	$	2,168	$	656		$	(20	)	$	9,023		$	2,245		$	14,072

The following table provides SCE's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,168	$	618	$	(28	)	$	8,454		$	2,070	$	13,282
Net income	—		—		—			745			—		745
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(294		)	—		(294		)
Dividends declared on preferred and preference stock	—		—		—			(56		)	—		(56		)
Stock-based compensation	—		6		—			(23		)	—		(17		)
Non-cash stock-based compensation	—		6		—			—			—		6
Balance at June 30, 2015	$	2,168	$	630	$	(26	)	$	8,826		$	2,070	$	13,668

XML

Variable Interest Entities

6 Months Ended

Jun. 30, 2016

Variable Interest Entities Disclosure [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 an entity that owns 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 Contracts

SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities ("QFs") that contain variable pricing provisions based on the price of natural gas. SCE has concluded that it is not the primary beneficiary of these VIEs since it does not control the commercial and operating activities of these entities. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is the operation and maintenance of the power plants.

As of the balance sheet date, the carrying amount of assets and liabilities in SCE's consolidated balance sheet that relate to its involvement with VIEs result from amounts due under the PPAs or the fair value of those derivative contracts. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 11 of the 2015 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 4,349 MW and 4,125 MW at June 30, 2016 and 2015, respectively, and the amounts that SCE paid to these projects were $92 million and $78 million for the three months ended June 30, 2016 and 2015, respectively, and $219 million and $181 million for six months ended June 30, 2016 and 2015, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.

Unconsolidated Trusts of SCE

SCE Trust I, Trust II, Trust III, Trust IV, and Trust V were formed in 2012, 2013, 2014, 2015 and 2016, respectively, for the exclusive purpose of issuing the 5.625%, 5.10%, 5.75%, 5.375% and 5.45% trust preference securities, respectively ("trust securities"). The trusts are VIEs. SCE has concluded that it is not the primary beneficiary of these VIEs as it does not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the trusts. SCE Trust I, Trust II, Trust III, Trust IV and Trust V issued to the public trust securities in the face amounts of $475 million, $400 million, $275 million, $325 million, and $300 million respectively, (cumulative, liquidation amounts of $25 per share) and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series F, Series G, Series H, Series J, and Series K Preference Stock issued by SCE in the principal amounts of $475 million, $400 million, $275 million, $325 million and $300 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities.

The Series F, Series G, Series H, Series J and Series K Preference Stock and the corresponding trust securities do not have a maturity date. Upon any redemption of any shares of the Series F, Series G, Series H, Series J or Series K Preference Stock, a corresponding dollar amount of trust securities will be redeemed by the applicable trust (see Note 12 for further information). The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities when and if 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 and Trust IV balance sheets as of June 30, 2016 and December 31, 2015, consisted of investments of $475 million, $400 million, $275 million and $325 million in the Series F, Series G, Series H and Series J Preference Stock, respectively, $475 million, $400 million, $275 million and $325 million of trust securities, respectively, and $10,000 each of common stock. The Trust V balance sheet as of June 30, 2016 consisted of investments of $300 million in the Series K Preference Stock, $300 million of trust securities, and $10,000 of common stock.

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

	Three months ended June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	6	$	5	$	4	$	5	$	4
Dividend distributions	6		5		4		5		4
2015
Dividend income	$	6	$	5	$	4	*		*
Dividend distributions	6		5		4		*		*

	Six months ended June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	13	$	10	$	8	$	9	$	5
Dividend distributions	13		10		8		9		5
2015
Dividend income	$	13	$	10	$	8	*		*
Dividend distributions	13		10		8		*		*

* Not applicable.

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2016

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 June 30, 2016 and December 31, 2015, nonperformance risk was not material for Edison International and SCE.

Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.

Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds and money market funds.

Level 2 – Edison International 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") and long-term power agreements. Edison International Parent and Other does not have any Level 3 assets and liabilities.

Assumptions are made in order to value derivative contracts in which observable inputs are not available. Changes in fair value are based on changes to forward market prices, including extrapolation of short-term observable inputs into forecasted prices for illiquid forward periods. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of fair value of derivative instruments.

SCE

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

	June 30, 2016
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	9	$	125		$	—	$	134
Other	18		—		—			—		18
Nuclear decommissioning trusts:
Stocks2	1,488		—		—			—		1,488
Fixed Income3	830		1,902		—			—		2,732
Short-term investments, primarily cash equivalents	57		117		—			—		174
Subtotal of nuclear decommissioning trusts4	2,375		2,019		—			—		4,394
Total assets	2,393		2,028		125			—		4,546
Liabilities at fair value
Derivative contracts	—		—		1,295			—		1,295
Total liabilities	—		—		1,295			—		1,295
Net assets (liabilities)	$	2,393	$	2,028	$	(1,170	)	$	—	$	3,251

	December 31, 2015
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1			Total
Assets at fair value
Derivative contracts	$	—	$	—	$	163		$	—		$	163
Other	28		—		—			—			28
Nuclear decommissioning trusts:
Stocks2	1,460		—		—			—			1,460
Fixed Income3	947		1,776		—			—			2,723
Short-term investments, primarily cash equivalents	91		81		—			—			172
Subtotal of nuclear decommissioning trusts4	2,498		1,857		—			—			4,355
Total assets	2,526		1,857		163			—			4,546
Liabilities at fair value
Derivative contracts	—		22		1,311			(15		)	1,318
Total liabilities	—		22		1,311			(15		)	1,318
Net assets (liabilities)	$	2,526	$	1,835	$	(1,148	)	$	15		$	3,228

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 71% and 70% of SCE's equity investments were located in the United States at June 30, 2016 and December 31, 2015, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $89 million and $111 million at June 30, 2016 and December 31, 2015, respectively.

⁴  Excludes net payables of $50 million and net payables of $24 million at June 30, 2016 and December 31, 2015, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.

Edison International Parent and Other

Edison International Parent and Other assets measured at fair value consisted of money market funds of $33 million and $29 million at June 30, 2016 and December 31, 2015, respectively, classified as Level 1.

SCE Fair Value of Level 3

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Fair value of net liabilities at beginning of period	$	(1,213	)	$	(976	)	$	(1,148	)	$	(902	)
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities1	43			(68		)	(22		)	(142		)
Fair value of net liabilities at end of period	$	(1,170	)	$	(1,044	)	$	(1,170	)	$	(1,044	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	19		$	(65	)	$	(54	)	$	(148	)

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 transfers between any levels during 2016 and 2015.

Valuation Techniques Used to Determine Fair Value

The process of determining fair value is the responsibility of SCE's risk management department, which reports to SCE's chief financial officer. This department obtains observable and unobservable inputs through broker quotes, exchanges and internal valuation techniques that use both standard and proprietary models to determine fair value. Each reporting period, the risk and finance departments collaborate to determine the appropriate fair value methodologies and classifications for each derivative. Inputs are validated for reasonableness by comparison against prior prices, other broker quotes and volatility fluctuation thresholds. Inputs used and valuations are reviewed period-over-period and compared with market conditions to determine reasonableness.

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
June 30, 2016	$	119	$	—	Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
December 31, 2015	152		—		Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
Tolling
June 30, 2016	3		1,293		Option model	Volatility of gas prices	15% - 41% (20%)
						Volatility of power prices	26% - 86% (30%)
						Power prices	$25.77 - $50.38 ($37.50)
December 31, 2015	10		1,297		Option model	Volatility of gas prices	15% - 58% (20%)
						Volatility of power prices	26% - 38% (30%)
						Power prices	$24.15 - $46.93 ($34.80)

¹  Prices are in dollars per megawatt-hour.

²  Prices are in dollars per million British thermal units.

Level 3 Fair Value Sensitivity

Congestion Revenue Rights

For CRRs, where SCE is the buyer, generally increases (decreases) in forecasted load in isolation would result in increases (decreases) to the fair value. In general, an increase (decrease) in electricity and gas prices at illiquid locations tends to result in increases (decreases) to fair value; however, changes in electricity and gas prices in opposite directions may have varying results on fair value.

Tolling Arrangements

The fair values of SCE's tolling arrangements contain intrinsic value and time value. Intrinsic value is the difference between the market price and strike price of the underlying commodity. Time value is made up of several components, including volatility, time to expiration, and interest rates. The option model for tolling arrangements reflects plant specific information such as operating and start-up costs.

For tolling arrangements where SCE is the buyer, increases in volatility of the underlying commodity prices would result in increases to fair value as it represents greater price movement risk. As power and gas prices increase, the fair value of tolling arrangements tends to increase. The valuation of tolling arrangements is also impacted by the correlation between gas and power prices. As the correlation increases, the fair value of tolling arrangements tends to decline.

Nuclear Decommissioning Trusts

SCE's nuclear decommissioning trust investments include equity securities, U.S. treasury securities and other fixed income securities. Equity and treasury securities are classified as Level 1 as fair value is determined by observable market prices in active or highly liquid and transparent markets. The remaining fixed income securities are classified as Level 2. The fair value of these financial instruments is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information.

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:

	June 30, 2016				December 31, 2015
(in millions)	Carrying Value		Fair Value		Carrying Value		Fair Value
SCE	$	10,503	$	12,457	$	10,539	$	11,592
Edison International	11,541		13,521		11,178		12,252

The fair value of Edison International 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.

XML

Debt and Credit Agreements

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Debt and Credit Agreements

Debt and Credit Agreements

Long-Term Debt

During the first quarter of 2016, Edison International issued $400 million of 2.95% senior notes due in 2023. The proceeds from these bonds were used to repay commercial paper borrowings and for general corporate purposes.

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. In July 2016, SCE and Edison International Parent extended the maturity dates to July 2021 for $2.72 billion and $1.23 billion of these facilities, respectively. The remaining $34 million and $16 million for the SCE and Edison International Parent credit facilities, respectively, will mature in July 2020. SCE's credit facility is generally used to support commercial paper borrowings and letters of credit issued for procurement-related collateral requirements, balancing account undercollections and for general corporate purposes, including working capital requirements to support operations and capital expenditures. Edison International Parent's credit facility is used to support commercial paper borrowings and for general corporate purposes.

At June 30, 2016, SCE's outstanding commercial paper, net of discount, was $506 million at a weighted-average interest rate of 0.60%. At June 30, 2016, letters of credit issued under SCE's credit facility aggregated $89 million and are scheduled to expire in twelve months or less. At December 31, 2015, the outstanding commercial paper was $49 million at a weighted-average interest rate of 0.51%.

At June 30, 2016, Edison International Parent's outstanding commercial paper, net of discount, was $294 million at a weighted-average interest rate of 0.69%. At December 31, 2015, the outstanding commercial paper was $646 million at a weighted-average interest rate of 0.78%.

XML

Derivative Instruments

6 Months Ended

Jun. 30, 2016

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 power purchase agreements. SCE's natural gas price exposure arises from natural gas purchased for the Mountainview power plant and peaker plants, QF contracts where pricing is based on a monthly natural gas index and power purchase agreements in which SCE has agreed to provide the natural gas needed for generation, referred to as tolling arrangements.

Credit and Default Risk

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

Certain power contracts contain master netting agreements or similar agreements, which generally allow counterparties subject to the agreement to setoff amounts when certain criteria are met, such as in the event of default. The objective of netting is to reduce credit exposure. Additionally, to reduce SCE's risk exposures counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.

Certain power contracts contain a provision that requires SCE to maintain an investment grade rating from each of the major credit rating agencies, referred to as a credit-risk-related contingent feature. If SCE's credit rating were to fall below investment grade, SCE may be required to post additional collateral to cover derivative liabilities and the related outstanding payables. The net fair value of all derivative liabilities with these credit-risk-related contingent features was $24 million and $38 million as of June 30, 2016 and December 31, 2015, respectively. SCE has posted $12 million collateral at June 30, 2016 and no collateral at December 31, 2015 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 June 30, 2016, SCE would be required to post $5 million of additional collateral 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:

	June 30, 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	$	66		$	69	$	135		$	196		$	1,100	$	1,296		$	1,161
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	65		$	69	$	134		$	195		$	1,100	$	1,295		$	1,161

	December 31, 2015
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	81		$	84	$	165		$	235		$	1,100	$	1,335		$	1,170
Gross amounts offset in the consolidated balance sheets	(2		)	—		(2		)	(2		)	—		(2		)	—
Cash collateral posted1	—			—		—			(15		)	—		(15		)	(15		)
Net amounts presented in the consolidated balance sheets	$	79		$	84	$	163		$	218		$	1,100	$	1,318		$	1,155

¹  In addition, at June 30, 2016, SCE received $4 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015, SCE had posted $31 million of collateral that is not offset against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets.

Income Statement Impact of Derivative Instruments

SCE recognizes realized gains and losses on derivative instruments as purchased power expense and expects that such gains or losses will be part of the purchase power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are recorded in cash flows from operating activities in the consolidated statements of cash flows.

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Realized losses	$	(25	)	$	(39	)	$	(52	)	$	(75	)
Unrealized gains (losses)	72			(16		)	8			(85		)

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	June 30, 2016	December 31, 2015
Electricity options, swaps and forwards	GWh	4,980	6,221
Natural gas options, swaps and forwards	Bcf	4	32
Congestion revenue rights	GWh	80,094	109,740
Tolling arrangements	GWh	65,998	70,663

XML

Income Taxes

6 Months Ended

Jun. 30, 2016

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:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Income from continuing operations before income taxes	$	259		$	412		$	591		$	837
Provision for income tax at federal statutory rate of 35%	91			144			207			293
Increase in income tax from:
State tax, net of federal benefit	4			5			11			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	2			(77		)	1			(62		)
Other	(6		)	3			(11		)	(5		)
Total income tax (benefit) expense from continuing operations	$	(47	)	$	6		$	(9	)	$	113
Effective tax rate	(18.1		)%	1.5		%	(1.5		)%	13.5		%
SCE:
Income from continuing operations before income taxes	$	317		$	419		$	683		$	860
Provision for income tax at federal statutory rate of 35%	111			147			239			301
Increase in income tax from:
State tax, net of federal benefit	6			2			15			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	(1		)	(75		)	(2		)	(65		)
Other	(7		)	2			(14		)	(8		)
Total income tax (benefit) expense from continuing operations	$	(29	)	$	7		$	21		$	115
Effective tax rate	(9.1		)%	1.7		%	3.1		%	13.4		%

¹   During the second quarter of 2016, SCE recorded $79 million for 2012 – 2014 incremental tax benefits related to repair deductions, which were flowed-through to customers ($133 million pre-tax).

The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates.

Repair Deductions

Previously, SCE recognized earnings and a regulatory asset for deferred income taxes related to 2012 – 2014 tax repair deductions. As a result of the CPUC's rate base offset in the 2015 GRC decision, SCE wrote down this regulatory asset in full during 2015. The after-tax charge was reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductions the CPUC used to establish the rate base offset was based on SCE's forecast of 2012 – 2014 tax repair deductions from the Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In April 2016, the CPUC granted SCE's request to reduce SCE's Base Revenue Requirement Balancing Account by $234 million during 2016 through 2020 subject to the outcome of audits that may be conducted by tax authorities. SCE refunded $133 million ($79 million after-tax) during the second quarter of 2016. The refunds result in flowing incremental tax benefits for 2012 – 2014 to customers through 2020. SCE did not record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings.

Tax Disputes

Tax Years 2007 – 2012

Edison International has reached a tentative settlement agreement with the IRS for the 2007 – 2012 tax years. The final agreement, when approved, is not expected to have a material impact on the financial statements.

During the second quarter of 2015, the Company received the IRS Revenue Agent Report for the 2010 – 2012 tax years. Edison International's and SCE's tax reserves were re-measured at that time and $94 million and $100 million, respectively, of income tax benefits were recorded in the comparable quarter for the prior year.

Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2007 – 2015 and 2003 – 2015, respectively.

XML

Compensation and Benefit Plans

6 Months Ended

Jun. 30, 2016

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Compensation and Benefit Plans

Compensation and Benefit Plans

Pension Plans

Edison International made contributions of $47 million during the six months ended June 30, 2016, which includes contributions of $37 million by SCE. Edison International expects to make contributions of $73 million during the remainder of 2016, which includes $58 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. Annual contributions to these plans are expected to be, at a minimum, equal to the related annual expense.

Pension expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	39		$	35		$	78		$	70
Interest cost	44			42			88			83
Expected return on plan assets	(56		)	(57		)	(112		)	(114		)
Amortization of prior service cost	1			1			2			2
Amortization of net loss1	9			9			18			18
Expense under accounting standards	$	37		$	30		$	74		$	59
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	28		$	29		$	56		$	57
SCE:
Service cost	$	38		$	34		$	76		$	69
Interest cost	41			37			82			75
Expected return on plan assets	(53		)	(54		)	(106		)	(107		)
Amortization of prior service cost	1			2			2			3
Amortization of net loss1	8			8			16			15
Expense under accounting standards	$	35		$	27		$	70		$	55
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	26		$	26		$	52		$	53

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $1 million, respectively, for the three months ended June 30, 2016, and $6 million and $3 million, respectively, for the six months ended June 30, 2016. The amount reclassified for Edison International and SCE was $4 million and $2 million, respectively, for the three months ended June 30, 2015 and $7 million and $4 million, respectively, for the six months ended June 30, 2015.

Postretirement Benefits Other Than Pensions

Edison International made contributions of $17 million during the six months ended June 30, 2016 and expects to make contributions of $16 million during the remainder of 2016, substantially all of which are expected to be made by SCE. Annual contributions 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 benefits with respect to its employees and former employees. A participating employer may terminate the PBOP benefits with respect to its employees and former employees, as may SCE (as Plan sponsor), and, accordingly, the participants' PBOP benefits are not vested benefits.

PBOP expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			57
Expected return on plan assets	(28		)	(29		)	(56		)	(57		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			6			—			12
Total expense	$	7		$	14		$	14		$	30
SCE:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			56
Expected return on plan assets	(28		)	(28		)	(56		)	(56		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			5			—			11
Total expense	$	7		$	14		$	14		$	29

Workforce Reductions

SCE continues to focus on productivity improvements to mitigate rate pressure from its capital program, optimize its cost structure and improve operational efficiency, which is expected to result in further workforce reductions through 2016. During the six months ended June 30, 2016, SCE increased the estimated impact for approved workforce reductions.

The following table provides a summary of changes in the accrued severance liability associated with these reductions:

(in millions)
Balance at January 1, 2016	$	22
Additions	13
Payments	(23		)
Balance at June 30, 2016	$	12

The liability presented in the table above is reflected in "Other current liabilities" on the consolidated balance sheets. The severance costs are included in "Operation and maintenance" on the consolidated income statements.

XML

Investments

6 Months Ended

Jun. 30, 2016

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)		June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Stocks	—	$	329	$	304	$	1,488	$	1,460
Municipal bonds	2054	675		691		854		840
U.S. government and agency securities	2046	1,002		1,070		1,107		1,128
Corporate bonds	2057	683		708		771		755
Short-term investments and receivables/payables1	One-year	121		144		124		148
Total		$	2,810	$	2,917	$	4,344	$	4,331

¹ Short-term investments include $85 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and matured by July 5, 2016 and January 5, 2016 as of June 30, 2016 and December 31, 2015, respectively.

Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion and $1.4 billion at June 30, 2016 and December 31, 2015, respectively.

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

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Balance at beginning of period	$	4,290		$	4,896		$	4,331		$	4,799
Gross realized gains	22			5			75			32
Gross realized losses	(1		)	(3		)	(4		)	(5		)
Unrealized gains (losses), net	72			(71		)	113			(27		)
Other-than-temporary impairments	(8		)	(8		)	(33		)	(12		)
Interest and dividends	32			32			60			60
Contributions	—			—			—			7
Income taxes	(24		)	(14		)	(42		)	(14		)
Decommissioning disbursements	(38		)	—			(154		)	—
Administrative expenses and other	(1		)	(1		)	(2		)	(4		)
Balance at end of period	$	4,344		$	4,836		$	4,344		$	4,836

Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE. Deferred tax liabilities related to net unrealized gains at June 30, 2016 were $375 million. Accordingly, the fair value of Trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $4.0 billion at June 30, 2016. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.

XML

Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 2016

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)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	309	$	382
Energy derivatives	135		159
Other	34		19
Total current	478		560
Long-term:
Deferred income taxes, net	4,176		3,757
Pensions and other postretirement benefits	836		849
Energy derivatives	1,041		1,027
Unamortized investments, net	156		182
San Onofre	942		1,043
Unamortized loss on reacquired debt	193		201
Regulatory balancing accounts	49		36
Environmental remediation	128		129
Other	271		288
Total long-term	7,792		7,512
Total regulatory assets	$	8,270	$	8,072

Regulatory Liabilities

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

(in millions)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	1,050	$	1,106
Other	22		22
Total current	1,072		1,128
Long-term:
Costs of removal	2,825		2,781
Recoveries in excess of ARO liabilities1	1,740		1,502
Regulatory balancing accounts	1,392		1,314
Other	60		79
Total long-term	6,017		5,676
Total regulatory liabilities	$	7,089	$	6,804

¹ Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9.

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)	June 30, 2016			December 31, 2015
Asset (liability)
Energy resource recovery account	$	(252	)	$	(439	)
New system generation balancing account	(195		)	(171		)
Public purpose programs and energy efficiency programs	(828		)	(683		)
Tax accounting memorandum account and pole loading balancing account	(68		)	(248		)
Base rate recovery balancing account	(535		)	(319		)
Department of Energy litigation memorandum account1	(122		)	—
Greenhouse gas auction revenue	(4		)	(75		)
FERC balancing accounts	40			74
Other	(120		)	(141		)
Liability	$	(2,084	)	$	(2,002	)

¹ Represents a refund from the Department of Energy's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. See "Note 11. Commitments and Contingencies—Contingencies—Spent Nuclear Fuel" for further discussion.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Indemnities

Edison International and SCE have various financial and performance guarantees and indemnity agreements, which are issued in the normal course of business.

Edison International and SCE have provided indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, and indemnities for specified environmental liabilities and income taxes with respect to assets sold. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated.

SCE has indemnified the City of Redlands, California in connection with Mountainview's California Energy Commission permit for cleanup or associated actions related to groundwater contaminated by perchlorate due to the disposal of filter cake at the City's solid waste landfill. The obligations under this agreement are not limited to a specific time period or subject to a maximum liability. SCE has not recorded a liability related to this indemnity.

Contingencies

In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business. Edison International and SCE believe the outcome of these other proceedings will not, individually or in the aggregate, materially affect its results of operations or liquidity.

San Onofre Related Matters

Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3.

San Onofre CPUC Proceedings

The San Onofre OII Settlement Agreement resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the related outages and subsequent shutdown of San Onofre. In May 2016, and in consideration of the CPUC's December 2015 decision sanctioning SCE for failing to disclose ex parte communications relevant to the San Onofre OII, the Assigned Commissioner and ALJ issued a ruling to reopen the record upon which the CPUC had, in November 2014, approved the San Onofre OII Settlement Agreement among SCE, TURN, ORA, SDG&E, the Coalition of California Utility Employees, and Friends of the Earth. The ruling also established a ban on all ex parte communications in the proceeding. The ruling established a briefing schedule for parties to address whether, in light of the ex parte rules violations, the San Onofre OII Settlement Agreement remains 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 asserts that the San Onofre OII Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of parties, however, have asked the CPUC in their comments to 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. SCE is unable to predict the outcome of this matter. The San Onofre OII Settlement Agreement does not affect proceedings related to recoveries from third parties described below, but does describe how shareholders and customers will share any recoveries.

Challenges related to San Onofre CPUC Proceedings

A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case appealed the dismissal to the Ninth Circuit in May 2015. Both the appeal and the application for rehearing remain pending.

In April 2015, the Alliance for Nuclear Responsibility ("A4NR") filed a petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement based on SCE's alleged failures to disclose communications between SCE and CPUC decision-makers pertaining to issues in the San Onofre OII. The petition seeks the reversal of the decision approving the San Onofre OII Settlement Agreement and reopening of the OII proceeding. Subsequently, TURN and ORA filed responses supporting A4NR's petition to reopen the San Onofre OII proceeding. In August 2015, ORA filed its own petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement seeking to set aside the settlement and reopen the San Onofre OII proceeding. SCE and SDG&E responded to this petition in September 2015. Both petitions remain pending before the CPUC.

In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief Executive Officer and Chief Financial Officer and was later amended to include SCE's former President as a defendant. The lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than initially reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International common stock between March 21, 2014 and June 24, 2015.

Subsequently and also in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same allegations was filed in August and was subsequently consolidated with the July 2015 federal derivative lawsuit.

In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the federal derivative lawsuits discussed above.

In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its Chief Executive Officer and Treasurer by an Edison International employee, alleging claims under the Employee Retirement Income Security Act ("ERISA"). The complaint purports to be filed on behalf of a class of Edison International employees who were participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between March 27, 2014 and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew or should have known that investment in the Edison International Stock Fund was imprudent because the price of Edison International common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte communications with CPUC decision-makers related to the San Onofre OII. In July 2016, the federal court granted the defendants' motion to dismiss the lawsuit with an opportunity for the plaintiffs to amend their complaint.

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

MHI Claims

SCE is also pursuing claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"), which designed and supplied the replacement steam generators. MHI warranted the replacement steam generators for an initial period of 20 years from acceptance and is contractually obligated to repair or replace defective items with dispatch and to pay specified damages for certain repairs. MHI's stated liability under the purchase agreement is limited to $138 million and excludes consequential damages, defined to include "the cost of replacement power;" however, limitations in the contract are subject to applicable exceptions both in the contract and under law. SCE has advised MHI that it believes one or more of such exceptions apply and that MHI's liability is not limited to $138 million. MHI has advised SCE that it disagrees. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce in accordance with the purchase contract seeking damages for all losses. In the request for arbitration, SCE alleges contract and tort claims and seeks at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI has denied any liability and has asserted counterclaims for $41 million, for which SCE has denied any liability. Each of the other San Onofre owners sued MHI, alleging claims arising from MHI's supplying the faulty steam generators. These litigation claims have been stayed pending the arbitration. The other co-owners (SDG&E and Riverside) have been added as additional claimants in the arbitration. The arbitration is being conducted pursuant to a confidentiality order issued by the arbitration panel. Hearings concluded on April 29, 2016. A decision may be issued by year-end 2016 but could be later.

SCE, on behalf of itself and the other San Onofre co-owners, has submitted seven invoices to MHI totaling $149 million for steam generator repair costs incurred through April 30, 2013. MHI paid the first invoice of $45 million, while reserving its right to challenge it and subsequently rejected a portion of the first invoice and has not paid further invoices, claiming further documentation is required, which SCE disputes. SCE recorded its share of the invoice paid (approximately $35 million) as a reduction of repair and inspection costs in 2012.

Under the San Onofre OII Settlement Agreement, recoveries from MHI (including amounts paid by MHI under the first invoice), if any, will first be applied to reimburse costs incurred in pursuing such recoveries, including litigation costs. To the extent SCE's share of recoveries from MHI exceed such costs, they will be allocated 50% to customers and 50% to SCE.

The first $282 million of SCE's customers' portion of such recoveries from MHI will be distributed to customers via a credit to a sub-account of SCE's Base Revenue Requirement Balancing Account ("BRRBA"), reducing revenue requirements from customers. Amounts in excess of the first $282 million distributable to SCE customers will reduce SCE's regulatory asset represented by the unamortized balance of investment in San Onofre base plant, reducing the revenue requirement needed to amortize such investment. The amortization period, however, will be unaffected. Any additional amounts received after the regulatory asset is recovered will be applied to the BRRBA.

The San Onofre OII Settlement Agreement provides the utilities with the discretion to resolve the MHI dispute without CPUC approval, but the utilities are obligated to use their best efforts to inform the CPUC of any settlement or other resolution of these disputes to the extent this is possible without compromising any aspect of the resolution. SCE and SDG&E have also agreed to allow the CPUC to review the documentation of any final resolution of the MHI dispute and the litigation costs incurred in pursuing claims against MHI to ensure they are not exorbitant in relation to the recovery obtained. There is no assurance that there will be any recovery from MHI or, if there is a recovery, that it will equal or exceed the litigation costs incurred to pursue the recovery.

Energy Efficiency Incentive Mechanism

In September 2015, the CPUC granted TURN and ORA requests for rehearing of prior CPUC decisions related to $74.5 million of incentive awards that SCE received for savings achieved by its 2006 – 2008 energy efficiency programs. In March 2016, ORA and TURN filed a joint proposal requesting that the CPUC recalculate SCE's 2006 – 2008 incentive awards and order SCE to refund $39.9 million to its customers. SCE disputes the assertion that SCE should be at risk to repay previously awarded incentives. SCE cannot predict the outcome of these petitions.

Long Beach Service Interruptions

In July 2015, SCE's customers who are served via the network portion of SCE's electric system in Long Beach, California experienced service interruptions due to multiple underground vault fires and underground cable failures. No personal injuries have been reported in connection with these events and, subject to applicable deductibles, SCE is generally insured against customer claims arising from these events. SCE instituted an internal investigation and commissioned an external investigation of these events and their causes, which revealed that the main cause of the interruptions was a lack of adequate management oversight of the downtown network system. The investigations also revealed deficiencies in maintaining the knowledge base on the configuration and operation of the system, and a lack of sophisticated controls needed to more efficiently and effectively prevent and respond to the cascading events that occurred. On July 14, 2016, the CPUC initiated an investigation ("Long Beach OII") of these events and their causes based on an investigation by the CPUC's Safety and Enforcement Division ("SED"). The SED investigation, among other things, identified problems with maintenance, inspection, and management of SCE's Long Beach electrical system, and emergency response and communications capabilities. The Long Beach OII will consider whether SCE violated statutes, rules or regulations, maintained adequate, accurate, and complete records, and provided sufficient emergency response and communications to various parties during the power outages. SCE has been directed to show cause at hearings why the CPUC should not find it in violation of the relevant statutes, rules and regulations. The OII does not propose a penalty amount. The CPUC may impose penalties in the amount of $500 to $50,000 per day per violation, but SCE is unable to estimate a possible loss or range of loss associated with any penalties that may be imposed by the CPUC in the Long Beach OII.

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 June 30, 2016, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites in which the upper end of the range of the costs is at least $1 million) was $130 million, including $79 million related to San Onofre. In addition to these sites, SCE also has 39 immaterial sites for which the total minimum recorded liability was $4 million. Of the $134 million total environmental remediation liability for SCE, $128 million has been recorded as a regulatory asset. SCE expects to recover $46 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $82 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.

The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $165 million and $7 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.

SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next four years are expected to range from $7 million to $23 million. Costs incurred for the six months ended June 30, 2016 and 2015 were $1 million and $3 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 2015 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. Prolonged drought conditions in California have also increased the duration of the wildfire season and the risk of severe wildfire events. SCE has approximately $910 million of third party insurance coverage for wildfire liabilities for the period from July 2016 to May 2017. SCE's program includes approximately $90 million in self-insurance at various levels within the $910 million of third party insurance coverage, which combined, equals approximately $1 billion. In addition, SCE has a self-insured retention of $10 million per wildfire occurrence. SCE may experience coverage reductions and/or increased insurance costs in future years. No assurance can be given that future losses will not exceed the limits of SCE's insurance coverage.

Spent Nuclear Fuel

Under federal law, the Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept 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. 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.

XML

Preferred and Preference Stock of SCE

6 Months Ended

Jun. 30, 2016

Preferred And Preference Stock Of Utility Disclosure [Abstract]

Preferred and Preference Stock of SCE

Preferred and Preference Stock of SCE

During the first quarter of 2016, SCE issued $300 million of 5.45% Series K Preference Stock (120,004 shares; cumulative, $2,500 liquidation value) to SCE Trust V, a special purpose entity formed to issue trust securities as discussed in Note 3. The Series K Preference Stock may be redeemed at par, in whole, but not in part, at any time prior to March 15, 2026 if certain changes in tax or investment company laws occur. On or after March 15, 2026, SCE may redeem the Series K shares at par, in whole or in part and distributions will accrue and be payable at a floating rate. The shares are not subject to mandatory redemption. The proceeds were used to redeem $125 million of SCE's Series D Preference Stock and for general corporate purposes.

XML

Accumulated Other Comprehensive Loss

6 Months Ended

Jun. 30, 2016

Equity [Abstract]

Accumulated Other Comprehensive Loss

Accumulated Other Comprehensive Loss

Edison International's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(54	)	$	(59	)	$	(56	)	$	(58	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(4		)
Reclassified from accumulated other comprehensive loss1	1			4			3			6
Change	1			3			3			2
Ending Balance	$	(53	)	$	(56	)	$	(53	)	$	(56	)

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

SCE's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(21	)	$	(27	)	$	(22	)	$	(28	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(1		)
Reclassified from accumulated other comprehensive loss1	1			2			2			3
Change	1			1			2			2
Ending Balance	$	(20	)	$	(26	)	$	(20	)	$	(26	)

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

XML

Interest and Other Income and Other Expenses

6 Months Ended

Jun. 30, 2016

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 June 30,				Six months ended June 30,
(in millions)	2016		2015		2016		2015
SCE interest and other income:
Equity allowance for funds used during construction	$	19	$	21	$	42	$	42
Increase in cash surrender value of life insurance policies and life insurance benefits	11		7		17		17
Interest income	2		2		3		3
Other	1		1		3		2
Total SCE interest and other income	33		31		65		64
Other income of Edison International Parent and Other1	—		12		—		18
Total Edison International interest and other income	$	33	$	43	$	65	$	82
SCE other expenses:
Civic, political and related activities and donations	8		9		$	12	$	14
Other	3		8		7		10
Total SCE other expenses	11		17		19		24
Total Edison International other expenses	$	11	$	17	$	19	$	24

¹  Reflects Edison Capital's income related to the sale of affordable housing projects for the three and six months ended June 30, 2015.

XML

Supplemental Cash Flows Information

6 Months Ended

Jun. 30, 2016

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flows Information

Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International					SCE
	Six months ended June 30,
(in millions)	2016		2015			2016		2015
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	228	$	230		$	221	$	222
Tax payments, net	12		3			32		125
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	156	$	136		$	—	$	147
Preferred and preference stock	12		18			12		18
Details of debt exchange:
Pollution-control bonds redeemed (2.875%)	$	—	$	(203	)	$	—	$	(203	)
Pollution-control bonds issued (1.875%)	—		203			—		203

SCE's accrued capital expenditures at June 30, 2016 and 2015 were $338 million and $393 million, respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid.

During the second quarter of 2015, SCE amended a power contract classified as a capital lease, which resulted in a reduction in the lease obligation and asset by $147 million.

XML

Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2016

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, a company that holds interests in subsidiaries that are engaged in competitive businesses focused on providing energy solutions to commercial and industrial customers, including distributed resources, engaging in competitive transmission opportunities, and exploring distributed water treatment and recycling. Such competitive business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutility subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements.

Edison International's and SCE's significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in the 2015 Form 10-K. This quarterly report should be read in conjunction with the financial statements and notes included in the 2015 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 of America for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three- and six-month periods ended June 30, 2016 are not necessarily indicative of the operating results for the full year.

The December 31, 2015 financial statement data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America.

Cash Equivalents

Cash Equivalents

Cash equivalents included 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.

Inventory

Inventory

Inventory is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being determined by the average cost method.

Revenue Recognition

Revenue Recognition

Operating revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the

end of each reporting period.

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 Adopted

On April 7, 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At June 30, 2016, the amount of debt issuance costs that are reflected as a deduction of "Long-term debt" was $75 million for SCE and $81 million for Edison International. At December 31, 2015 the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a deduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International.

On April 15, 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements.

Accounting Guidance Not Yet Adopted

On May 28, 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. On July 9, 2015, the FASB approved a one-year deferral, updating the effective date to January 1, 2018.Edison International and SCE are currently evaluating this guidance and cannot determine the impact of this standard at this time. Edison International and SCE anticipates adopting the standard using the modified retrospective application which means that 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.

On January 5, 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net income. 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.

On February 25, 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 classify leases with a term of more than one year as either operating or finance leases and will need to recognize a right-of-use asset and a lease liability. 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 front-loaded expense pattern. 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. This guidance is effective January 1, 2019 but early adoption is permitted. Edison International and SCE are currently evaluating this new guidance and cannot determine the impact of this standard at this time.

On March 30, 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Under this new guidance, the tax effects related to share based payments will be recorded through the income statement. Currently, tax benefits in excess of compensation cost ("windfalls") are recorded in equity, and tax deficiencies ("shortfalls") are recorded in equity to the extent of previous windfalls, and then to the income statement. This guidance is effective January 1, 2017 but early adoption is permitted. The new standard also revised reporting on the statement of cash flows. Edison International and SCE are currently evaluating this new guidance.

On June 16, 2016, the FASB issued an accounting standards update to amend the guidance on the impairment of financial instruments. The new guidance adds an impairment model, known as the current expected credit loss model, which was based on expected losses rather than incurred losses. This guidance applies to most debt instruments, trade receivables, lease receivables, financial guarantee contracts, and loan commitments. However, available-for-sale debt securities are excluded from the model's scope. This guidance is effective on January 1, 2020, but early adoption no earlier than January 1, 2019 is permitted. Edison International and SCE are currently evaluating this new guidance.

XML

Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Cash Equivalents

The cash equivalents were as follows:

	Edison International				SCE
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Money market funds	$	36	$	37	$	4	$	8

Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows:

	Edison International				SCE
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Book balances reclassified to accounts payable	$	99	$	162	$	99	$	158

EPS Attributable to Edison International Common Shareholders

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

	Three months ended June 30,				Six months ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$	278	$	379	$	547	$	678
Participating securities dividends	—		—		—		—
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Basic earnings per share – continuing operations	$	0.86	$	1.16	$	1.68	$	2.08
Diluted earnings per share – continuing operations:
Income from continuing operations available to common shareholders	$	278	$	379	$	547	$	678
Income impact of assumed conversions	—		—		—		—
Income from continuing operations available to common shareholders and assumed conversions	$	278	$	379	$	547	$	678
Weighted average common shares outstanding	326		326		326		326
Incremental shares from assumed conversions	3		2		3		3
Adjusted weighted average shares – diluted	329		328		329		329
Diluted earnings per share – continuing operations	$	0.85	$	1.15	$	1.66	$	2.06

XML

Consolidated Statements of Changes in Equity (Tables)

6 Months Ended

Jun. 30, 2016

Schedule of Capitalization, Equity [Line Items]

Schedule of changes in equity

The following table provides Edison International's changes in equity for the six months ended June 30, 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	—		—			546			546			61			607
Other comprehensive income	—		3			—			3			—			3
Common stock dividends declared ($0.96 per share)	—		—			(313		)	(313		)	—			(313		)
Dividends to noncontrolling interests	—		—			—			—			(61		)	(61		)
Stock-based compensation	3		—			(60		)	(57		)	—			(57		)
Non-cash stock-based compensation	12		—			—			12			—			12
Issuance of preference stock	—		—			—			—			294			294
Redemption of preference stock	—		—			(2		)	(2		)	(123		)	(125		)
Balance at June 30, 2016	$	2,499	$	(53	)	$	9,111		$	11,557		$	2,191		$	13,748

The following table provides Edison International's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,445	$	(58	)	$	8,573		$	10,960		$	2,022		$	12,982
Net income	—		—			678			678			56			734
Other comprehensive loss	—		2			—			2			—			2
Common stock dividends declared ($0.835 per share)	—		—			(272		)	(272		)	—			(272		)
Dividends to noncontrolling interests	—		—			—			—			(56		)	(56		)
Stock-based compensation	15		—			(70		)	(55		)	—			(55		)
Non-cash stock-based compensation	12		—			—			12			—			12
Balance at June 30, 2015	$	2,472	$	(56	)	$	8,909		$	11,325		$	2,022		$	13,347

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 six months ended June 30, 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	—		—			—			662			—			662
Other comprehensive income	—		—			2			—			—			2
Dividends declared on common stock	—		—			—			(340		)	—			(340		)
Dividends declared on preferred and preference stock	—		—			—			(61		)	—			(61		)
Stock-based compensation	—		2			—			(40		)	—			(38		)
Non-cash stock-based compensation	—		6			—			—			—			6
Issuance of preference stock	—		(6		)	—			—			300			294
Redemption of preference stock	—		2			—			(2		)	(125		)	(125		)
Balance at June 30, 2016	$	2,168	$	656		$	(20	)	$	9,023		$	2,245		$	14,072

The following table provides SCE's changes in equity for the six months ended June 30, 2015:

	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, 2014	$	2,168	$	618	$	(28	)	$	8,454		$	2,070	$	13,282
Net income	—		—		—			745			—		745
Other comprehensive income	—		—		2			—			—		2
Dividends declared on common stock	—		—		—			(294		)	—		(294		)
Dividends declared on preferred and preference stock	—		—		—			(56		)	—		(56		)
Stock-based compensation	—		6		—			(23		)	—		(17		)
Non-cash stock-based compensation	—		6		—			—			—		6
Balance at June 30, 2015	$	2,168	$	630	$	(26	)	$	8,826		$	2,070	$	13,668

XML

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	6	$	5	$	4	$	5	$	4
Dividend distributions	6		5		4		5		4
2015
Dividend income	$	6	$	5	$	4	*		*
Dividend distributions	6		5		4		*		*

	Six months ended June 30,
(in millions)	Trust I		Trust II		Trust III		Trust IV		Trust V
2016
Dividend income	$	13	$	10	$	8	$	9	$	5
Dividend distributions	13		10		8		9		5
2015
Dividend income	$	13	$	10	$	8	*		*
Dividend distributions	13		10		8		*		*

* Not applicable.

XML

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

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:

	June 30, 2016				December 31, 2015
(in millions)	Carrying Value		Fair Value		Carrying Value		Fair Value
SCE	$	10,503	$	12,457	$	10,539	$	11,592
Edison International	11,541		13,521		11,178		12,252

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:

	June 30, 2016
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1		Total
Assets at fair value
Derivative contracts	$	—	$	9	$	125		$	—	$	134
Other	18		—		—			—		18
Nuclear decommissioning trusts:
Stocks2	1,488		—		—			—		1,488
Fixed Income3	830		1,902		—			—		2,732
Short-term investments, primarily cash equivalents	57		117		—			—		174
Subtotal of nuclear decommissioning trusts4	2,375		2,019		—			—		4,394
Total assets	2,393		2,028		125			—		4,546
Liabilities at fair value
Derivative contracts	—		—		1,295			—		1,295
Total liabilities	—		—		1,295			—		1,295
Net assets (liabilities)	$	2,393	$	2,028	$	(1,170	)	$	—	$	3,251

	December 31, 2015
(in millions)	Level 1		Level 2		Level 3			Netting and Collateral1			Total
Assets at fair value
Derivative contracts	$	—	$	—	$	163		$	—		$	163
Other	28		—		—			—			28
Nuclear decommissioning trusts:
Stocks2	1,460		—		—			—			1,460
Fixed Income3	947		1,776		—			—			2,723
Short-term investments, primarily cash equivalents	91		81		—			—			172
Subtotal of nuclear decommissioning trusts4	2,498		1,857		—			—			4,355
Total assets	2,526		1,857		163			—			4,546
Liabilities at fair value
Derivative contracts	—		22		1,311			(15		)	1,318
Total liabilities	—		22		1,311			(15		)	1,318
Net assets (liabilities)	$	2,526	$	1,835	$	(1,148	)	$	15		$	3,228

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 71% and 70% of SCE's equity investments were located in the United States at June 30, 2016 and December 31, 2015, respectively.

³  Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $89 million and $111 million at June 30, 2016 and December 31, 2015, respectively.

⁴  Excludes net payables of $50 million and net payables of $24 million at June 30, 2016 and December 31, 2015, 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 June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Fair value of net liabilities at beginning of period	$	(1,213	)	$	(976	)	$	(1,148	)	$	(902	)
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities1	43			(68		)	(22		)	(142		)
Fair value of net liabilities at end of period	$	(1,170	)	$	(1,044	)	$	(1,170	)	$	(1,044	)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$	19		$	(65	)	$	(54	)	$	(148	)

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
June 30, 2016	$	119	$	—	Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
December 31, 2015	152		—		Market simulation model and auction prices	Load forecast	6,289 MW - 24,349 MW
						Power prices1	$0 - $110.44
						Gas prices2	$1.98 - $5.72
Tolling
June 30, 2016	3		1,293		Option model	Volatility of gas prices	15% - 41% (20%)
						Volatility of power prices	26% - 86% (30%)
						Power prices	$25.77 - $50.38 ($37.50)
December 31, 2015	10		1,297		Option model	Volatility of gas prices	15% - 58% (20%)
						Volatility of power prices	26% - 38% (30%)
						Power prices	$24.15 - $46.93 ($34.80)

¹  Prices are in dollars per megawatt-hour.

²  Prices are in dollars per million British thermal units.

XML

Derivative Instruments (Tables) - Southern California Edison

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Instruments

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

	June 30, 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	$	66		$	69	$	135		$	196		$	1,100	$	1,296		$	1,161
Gross amounts offset in the consolidated balance sheets	(1		)	—		(1		)	(1		)	—		(1		)	—
Cash collateral posted1	—			—		—			—			—		—			—
Net amounts presented in the consolidated balance sheets	$	65		$	69	$	134		$	195		$	1,100	$	1,295		$	1,161

	December 31, 2015
	Derivative Assets								Derivative Liabilities								Net Liability
(in millions)	Short-Term			Long-Term		Subtotal			Short-Term			Long-Term		Subtotal
Commodity derivative contracts
Gross amounts recognized	$	81		$	84	$	165		$	235		$	1,100	$	1,335		$	1,170
Gross amounts offset in the consolidated balance sheets	(2		)	—		(2		)	(2		)	—		(2		)	—
Cash collateral posted1	—			—		—			(15		)	—		(15		)	(15		)
Net amounts presented in the consolidated balance sheets	$	79		$	84	$	163		$	218		$	1,100	$	1,318		$	1,155

¹  In addition, at June 30, 2016, SCE received $4 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015, SCE had posted $31 million of collateral that is not offset against derivative liabilities and is reflected in "Other current assets" 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 June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Realized losses	$	(25	)	$	(39	)	$	(52	)	$	(75	)
Unrealized gains (losses)	72			(16		)	8			(85		)

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	June 30, 2016	December 31, 2015
Electricity options, swaps and forwards	GWh	4,980	6,221
Natural gas options, swaps and forwards	Bcf	4	32
Congestion revenue rights	GWh	80,094	109,740
Tolling arrangements	GWh	65,998	70,663

XML

Income Taxes (Tables)

6 Months Ended

Jun. 30, 2016

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:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Income from continuing operations before income taxes	$	259		$	412		$	591		$	837
Provision for income tax at federal statutory rate of 35%	91			144			207			293
Increase in income tax from:
State tax, net of federal benefit	4			5			11			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	2			(77		)	1			(62		)
Other	(6		)	3			(11		)	(5		)
Total income tax (benefit) expense from continuing operations	$	(47	)	$	6		$	(9	)	$	113
Effective tax rate	(18.1		)%	1.5		%	(1.5		)%	13.5		%
SCE:
Income from continuing operations before income taxes	$	317		$	419		$	683		$	860
Provision for income tax at federal statutory rate of 35%	111			147			239			301
Increase in income tax from:
State tax, net of federal benefit	6			2			15			16
Property-related1	(138		)	(69		)	(217		)	(129		)
Change related to uncertain tax positions	(1		)	(75		)	(2		)	(65		)
Other	(7		)	2			(14		)	(8		)
Total income tax (benefit) expense from continuing operations	$	(29	)	$	7		$	21		$	115
Effective tax rate	(9.1		)%	1.7		%	3.1		%	13.4		%

¹   During the second quarter of 2016, SCE recorded $79 million for 2012 – 2014 incremental tax benefits related to repair deductions, which were flowed-through to customers ($133 million pre-tax).

XML

Compensation and Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2016

Pension Plans

Pension and Other Postretirement Benefits

Expense Components for Plans

Pension expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	39		$	35		$	78		$	70
Interest cost	44			42			88			83
Expected return on plan assets	(56		)	(57		)	(112		)	(114		)
Amortization of prior service cost	1			1			2			2
Amortization of net loss1	9			9			18			18
Expense under accounting standards	$	37		$	30		$	74		$	59
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	28		$	29		$	56		$	57
SCE:
Service cost	$	38		$	34		$	76		$	69
Interest cost	41			37			82			75
Expected return on plan assets	(53		)	(54		)	(106		)	(107		)
Amortization of prior service cost	1			2			2			3
Amortization of net loss1	8			8			16			15
Expense under accounting standards	$	35		$	27		$	70		$	55
Regulatory adjustment	(9		)	(1		)	(18		)	(2		)
Total expense recognized	$	26		$	26		$	52		$	53

¹  Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $1 million, respectively, for the three months ended June 30, 2016, and $6 million and $3 million, respectively, for the six months ended June 30, 2016. The amount reclassified for Edison International and SCE was $4 million and $2 million, respectively, for the three months ended June 30, 2015 and $7 million and $4 million, respectively, for the six months ended June 30, 2015.

Postretirement Benefits Other Than Pensions

Pension and Other Postretirement Benefits

Expense Components for Plans

PBOP expense components for continuing operations are:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Edison International:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			57
Expected return on plan assets	(28		)	(29		)	(56		)	(57		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			6			—			12
Total expense	$	7		$	14		$	14		$	30
SCE:
Service cost	$	10		$	12		$	20		$	24
Interest cost	26			28			52			56
Expected return on plan assets	(28		)	(28		)	(56		)	(56		)
Amortization of prior service cost	(1		)	(3		)	(2		)	(6		)
Amortization of net loss	—			5			—			11
Total expense	$	7		$	14		$	14		$	29

Southern California Edison

Pension and Other Postretirement Benefits

Workforce reductions

The following table provides a summary of changes in the accrued severance liability associated with these reductions:

(in millions)
Balance at January 1, 2016	$	22
Additions	13
Payments	(23		)
Balance at June 30, 2016	$	12

XML

Investments (Tables) - Southern California Edison

6 Months Ended

Jun. 30, 2016

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)		June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Stocks	—	$	329	$	304	$	1,488	$	1,460
Municipal bonds	2054	675		691		854		840
U.S. government and agency securities	2046	1,002		1,070		1,107		1,128
Corporate bonds	2057	683		708		771		755
Short-term investments and receivables/payables1	One-year	121		144		124		148
Total		$	2,810	$	2,917	$	4,344	$	4,331

¹ Short-term investments include $85 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and matured by July 5, 2016 and January 5, 2016 as of June 30, 2016 and December 31, 2015, 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 June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Balance at beginning of period	$	4,290		$	4,896		$	4,331		$	4,799
Gross realized gains	22			5			75			32
Gross realized losses	(1		)	(3		)	(4		)	(5		)
Unrealized gains (losses), net	72			(71		)	113			(27		)
Other-than-temporary impairments	(8		)	(8		)	(33		)	(12		)
Interest and dividends	32			32			60			60
Contributions	—			—			—			7
Income taxes	(24		)	(14		)	(42		)	(14		)
Decommissioning disbursements	(38		)	—			(154		)	—
Administrative expenses and other	(1		)	(1		)	(2		)	(4		)
Balance at end of period	$	4,344		$	4,836		$	4,344		$	4,836

XML

Regulatory Assets and Liabilities (Tables) - Southern California Edison

6 Months Ended

Jun. 30, 2016

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)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	309	$	382
Energy derivatives	135		159
Other	34		19
Total current	478		560
Long-term:
Deferred income taxes, net	4,176		3,757
Pensions and other postretirement benefits	836		849
Energy derivatives	1,041		1,027
Unamortized investments, net	156		182
San Onofre	942		1,043
Unamortized loss on reacquired debt	193		201
Regulatory balancing accounts	49		36
Environmental remediation	128		129
Other	271		288
Total long-term	7,792		7,512
Total regulatory assets	$	8,270	$	8,072

Regulatory Liabilities Included on the Consolidated Balance Sheets

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

(in millions)	June 30, 2016		December 31, 2015
Current:
Regulatory balancing accounts	$	1,050	$	1,106
Other	22		22
Total current	1,072		1,128
Long-term:
Costs of removal	2,825		2,781
Recoveries in excess of ARO liabilities1	1,740		1,502
Regulatory balancing accounts	1,392		1,314
Other	60		79
Total long-term	6,017		5,676
Total regulatory liabilities	$	7,089	$	6,804

¹ Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9.

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)	June 30, 2016			December 31, 2015
Asset (liability)
Energy resource recovery account	$	(252	)	$	(439	)
New system generation balancing account	(195		)	(171		)
Public purpose programs and energy efficiency programs	(828		)	(683		)
Tax accounting memorandum account and pole loading balancing account	(68		)	(248		)
Base rate recovery balancing account	(535		)	(319		)
Department of Energy litigation memorandum account1	(122		)	—
Greenhouse gas auction revenue	(4		)	(75		)
FERC balancing accounts	40			74
Other	(120		)	(141		)
Liability	$	(2,084	)	$	(2,002	)

¹ Represents a refund from the Department of Energy's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. See "Note 11. Commitments and Contingencies—Contingencies—Spent Nuclear Fuel" for further discussion.

XML

Accumulated Other Comprehensive Loss (Tables)

6 Months Ended

Jun. 30, 2016

Equity [Abstract]

Components of Accumulated Other Comprehensive Loss

Edison International's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(54	)	$	(59	)	$	(56	)	$	(58	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(4		)
Reclassified from accumulated other comprehensive loss1	1			4			3			6
Change	1			3			3			2
Ending Balance	$	(53	)	$	(56	)	$	(53	)	$	(56	)

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

SCE's accumulated other comprehensive loss, net of tax consist of:

	Three months ended June 30,						Six months ended June 30,
(in millions)	2016			2015			2016			2015
Beginning balance	$	(21	)	$	(27	)	$	(22	)	$	(28	)
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	—			(1		)	—			(1		)
Reclassified from accumulated other comprehensive loss1	1			2			2			3
Change	1			1			2			2
Ending Balance	$	(20	)	$	(26	)	$	(20	)	$	(26	)

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

XML

Interest and Other Income and Other Expenses (Tables)

6 Months Ended

Jun. 30, 2016

Other Income and Expenses [Abstract]

Interest and Other Income and Expenses

Interest and other income and other expenses are as follows:

	Three months ended June 30,				Six months ended June 30,
(in millions)	2016		2015		2016		2015
SCE interest and other income:
Equity allowance for funds used during construction	$	19	$	21	$	42	$	42
Increase in cash surrender value of life insurance policies and life insurance benefits	11		7		17		17
Interest income	2		2		3		3
Other	1		1		3		2
Total SCE interest and other income	33		31		65		64
Other income of Edison International Parent and Other1	—		12		—		18
Total Edison International interest and other income	$	33	$	43	$	65	$	82
SCE other expenses:
Civic, political and related activities and donations	8		9		$	12	$	14
Other	3		8		7		10
Total SCE other expenses	11		17		19		24
Total Edison International other expenses	$	11	$	17	$	19	$	24

¹  Reflects Edison Capital's income related to the sale of affordable housing projects for the three and six months ended June 30, 2015.

XML

Supplemental Cash Flows Information (Tables)

6 Months Ended

Jun. 30, 2016

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flows Information

Supplemental cash flows information for continuing operations is:

	Edison International					SCE
	Six months ended June 30,
(in millions)	2016		2015			2016		2015
Cash payments for interest and taxes:
Interest, net of amounts capitalized	$	228	$	230		$	221	$	222
Tax payments, net	12		3			32		125
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock	$	156	$	136		$	—	$	147
Preferred and preference stock	12		18			12		18
Details of debt exchange:
Pollution-control bonds redeemed (2.875%)	$	—	$	(203	)	$	—	$	(203	)
Pollution-control bonds issued (1.875%)	—		203			—		203

XML

Summary of Significant Accounting Policies (Organization and Basis of Presentation) (Details) mi² in Thousands	6 Months Ended
	Jun. 30, 2016 mi²
Southern California Edison | Electric Utility
Summary of Significant Accounting Policies [Line Items]
Supply of electricity, area covered (square mile)	50

XML

Summary of Significant Accounting Policies (Cash Equivalents) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Cash and Cash Equivalents Items [Line Items]
Money market funds	$ 36	$ 37
Book balances reclassified to accounts payable	99	162
Southern California Edison
Cash and Cash Equivalents Items [Line Items]
Money market funds	4	8
Book balances reclassified to accounts payable	$ 99	$ 158

XML

Summary of Significant Accounting Policies (Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic earnings per share – continuing operations:
Income from continuing operations attributable to common shareholders	$ 278	$ 379	$ 547	$ 678
Participating securities dividends	0	0	0	0
Income from continuing operations available to common shareholders	$ 278	$ 379	$ 547	$ 678
Weighted average common shares outstanding (in shares)	326,000,000	326,000,000	326,000,000	326,000,000
Basic earnings per share – continuing operations (in dollars per share)	$ 0.86	$ 1.16	$ 1.68	$ 2.08
Diluted earnings per share – continuing operations:
Income from continuing operations available to common shareholders	$ 278	$ 379	$ 547	$ 678
Income impact of assumed conversions	0	0	0	0
Income from continuing operations available to common shareholders and assumed conversions	$ 278	$ 379	$ 547	$ 678
Weighted average common shares outstanding (in shares)	326,000,000	326,000,000	326,000,000	326,000,000
Incremental shares from assumed conversions (in shares)	3,000,000	2,000,000	3,000,000	3,000,000
Adjusted weighted average shares - diluted (in shares)	329,000,000	328,000,000	329,000,000	329,000,000
Diluted earnings per share – continuing operations (in dollars per share)	$ 0.85	$ 1.15	$ 1.66	$ 2.06
Stock-Based Compensation Awards
Diluted earnings per share – continuing operations:
Stock-based compensation awards excluded from the computation of diluted earnings per share (in shares)	42,890	1,981,596	47,861	1,981,596

XML

Summary of Significant Accounting Policies (New Accounting Guidance) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	$ 81
Southern California Edison
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	$ 75
Accounting Standards Update 2015-03 | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		$ 81
Accounting Standards Update 2015-03 | Other long-term assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		(81)
Accounting Standards Update 2015-03 | Southern California Edison | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		77
Accounting Standards Update 2015-03 | Southern California Edison | Other long-term assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		$ (77)

XML

Consolidated Statements of Changes in Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net income			$ 607	$ 734
Net income	$ 304	$ 406	599	724
Net Income (Loss) Attributable to Parent	276	379	546	678
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			13,388	12,982
Other comprehensive income (loss)	1	3	3	2
Dividends declared on common stock			(313)	(272)
Dividends to noncontrolling interests			(61)	(56)
Stock-based compensation			(57)	(55)
Non-cash stock-based compensation			12	12
Issuance of preference stock			294
Redemption of preference stock			(125)
Balance, at the end of the period	$ 13,748	$ 13,347	$ 13,748	$ 13,347
Dividends declared per common share (in dollars per share)	$ 0.4800	$ 0.4175	$ 0.96	$ 0.8350
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			$ 2,484	$ 2,445
Stock-based compensation			3	15
Non-cash stock-based compensation			12	12
Balance, at the end of the period	$ 2,499	$ 2,472	2,499	2,472
Accumulated Other Comprehensive Loss
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			(56)	(58)
Other comprehensive income (loss)			3	2
Balance, at the end of the period	(53)	(56)	(53)	(56)
Retained Earnings
Net income			546	678
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			8,940	8,573
Dividends declared on common stock			(313)	(272)
Stock-based compensation			(60)	(70)
Redemption of preference stock			(2)
Balance, at the end of the period	9,111	8,909	9,111	8,909
Subtotal
Net income			546	678
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			11,368	10,960
Other comprehensive income (loss)			3	2
Dividends declared on common stock			(313)	(272)
Stock-based compensation			(57)	(55)
Non-cash stock-based compensation			12	12
Redemption of preference stock			(2)
Balance, at the end of the period	11,557	11,325	11,557	11,325
Preferred and preference stock
Net income			61	56
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			2,020	2,022
Dividends to noncontrolling interests			(61)	(56)
Issuance of preference stock			294
Redemption of preference stock			(123)
Balance, at the end of the period	2,191	2,022	2,191	2,022
Southern California Edison
Net income	346	412	662	745
Net Income (Loss) Attributable to Parent	315	384	601	689
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			13,672	13,282
Other comprehensive income (loss)	1	1	2	2
Dividends declared on common stock			(340)	(294)
Dividends declared on preferred and preference stock			(61)	(56)
Stock-based compensation			(38)	(17)
Non-cash stock-based compensation			6	6
Issuance of preference stock			294
Redemption of preference stock			(125)
Balance, at the end of the period	14,072	13,668	14,072	13,668
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	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			652	618
Stock-based compensation			2	6
Non-cash stock-based compensation			6	6
Issuance of preference stock			(6)
Redemption of preference stock			2
Balance, at the end of the period	656	630	656	630
Southern California Edison | Accumulated Other Comprehensive Loss
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			(22)	(28)
Other comprehensive income (loss)			2	2
Balance, at the end of the period	(20)	(26)	(20)	(26)
Southern California Edison | Retained Earnings
Net income			662	745
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			8,804	8,454
Dividends declared on common stock			(340)	(294)
Dividends declared on preferred and preference stock			(61)	(56)
Stock-based compensation			(40)	(23)
Redemption of preference stock			(2)
Balance, at the end of the period	9,023	8,826	9,023	8,826
Southern California Edison | Preferred and preference stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance, at the beginning of the period			2,070	2,070
Issuance of preference stock			300
Redemption of preference stock			(125)
Balance, at the end of the period	$ 2,245	$ 2,070	$ 2,245	$ 2,070

XML

Variable Interest Entities (Details) - Southern California Edison	3 Months Ended			6 Months Ended		12 Months Ended
	Jun. 30, 2016 USD ($) $ / shares MW	Mar. 31, 2016 $ / shares	Jun. 30, 2015 USD ($) MW	Jun. 30, 2016 USD ($) $ / shares MW	Jun. 30, 2015 USD ($) MW	Dec. 31, 2015 USD ($) $ / shares
Series K Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)		5.45%
Liquidation value (in dollars per share) | $ / shares		$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Power Purchase Contracts
Details of projects or entities
Power generating capacity (in megawatts) | MW	4,349		4,125	4,349	4,125
Payments to unconsolidated VIEs for power purchase contracts	$ 92,000,000		$ 78,000,000	$ 219,000,000	$ 181,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust I
Unconsolidated Trust
Common stock	10,000			10,000		$ 10,000
Dividend income	6,000,000		6,000,000	13,000,000	13,000,000
Dividend distributions	6,000,000		6,000,000	$ 13,000,000	13,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust I | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)				5.625%		5.625%
Liquidation preference	$ 475,000,000			$ 475,000,000		$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25			$ 25		$ 25
Common stock	$ 10,000			$ 10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust I | Series F Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)				5.625%		5.625%
Liquidation preference	$ 475,000,000			$ 475,000,000		$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500			$ 2,500		$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust II
Unconsolidated Trust
Common stock	$ 10,000			$ 10,000		$ 10,000
Dividend income	5,000,000		5,000,000	10,000,000	10,000,000
Dividend distributions	5,000,000		5,000,000	$ 10,000,000	10,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust II | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)				5.10%		5.10%
Liquidation preference	$ 400,000,000			$ 400,000,000		$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25			$ 25		$ 25
Variable Interest Entity, Not Primary Beneficiary | SCE Trust II | Series G Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)				5.10%		5.10%
Liquidation preference	$ 400,000,000			$ 400,000,000		$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500			$ 2,500		$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust III
Unconsolidated Trust
Common stock	$ 10,000			$ 10,000		$ 10,000
Dividend income	4,000,000		4,000,000	8,000,000	8,000,000
Dividend distributions	4,000,000		$ 4,000,000	$ 8,000,000	$ 8,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust III | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)				5.75%		5.75%
Liquidation preference	$ 275,000,000			$ 275,000,000		$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25			$ 25		$ 25
Variable Interest Entity, Not Primary Beneficiary | SCE Trust III | Series H Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)				5.75%		5.75%
Liquidation preference	$ 275,000,000			$ 275,000,000		$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500			$ 2,500		$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust IV
Unconsolidated Trust
Common stock	$ 10,000			$ 10,000		$ 10,000
Dividend income	5,000,000			9,000,000
Dividend distributions	5,000,000			$ 9,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust IV | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)				5.375%		5.375%
Liquidation preference	$ 325,000,000			$ 325,000,000		$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25			$ 25		$ 25
Variable Interest Entity, Not Primary Beneficiary | SCE Trust IV | Series J Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)				5.375%		5.375%
Liquidation preference	$ 325,000,000			$ 325,000,000		$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500			$ 2,500		$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust V
Unconsolidated Trust
Common stock	$ 10,000			$ 10,000
Dividend income	4,000,000			5,000,000
Dividend distributions	4,000,000			$ 5,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust V | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)				5.45%
Liquidation preference	$ 300,000,000			$ 300,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25			$ 25
Common stock	$ 10,000			$ 10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust V | Series K Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)				5.45%
Liquidation preference	$ 300,000,000			$ 300,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500			$ 2,500

XML

Fair Value Measurements (Fair Value by Level) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014
Assets at fair value
Nuclear decommissioning trusts	$ 4,344		$ 4,331
Southern California Edison
Assets at fair value
Nuclear decommissioning trusts	$ 4,344	$ 4,290	$ 4,331	$ 4,836	$ 4,896	$ 4,799
Liabilities at fair value
Percentage of equity investments located in the United States (as a percent)	71.00%		70.00%
Collateralized mortgage obligations and other asset backed securities	$ 89		$ 111
Payables, net, related to investments	50		24
Southern California Edison | Fair Value, Measurements, Recurring
Assets at fair value
Derivative contracts	134		163
Other	18		28
Nuclear decommissioning trusts	4,394		4,355
Total assets	4,546		4,546
Liabilities at fair value
Derivative contracts	1,295		1,318
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset			(15)
Total liabilities	1,295		1,318
Net assets (liabilities)	3,251		3,228
Southern California Edison | Fair Value, Measurements, Recurring | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,488		1,460
Southern California Edison | Fair Value, Measurements, Recurring | Fixed income
Assets at fair value
Nuclear decommissioning trusts	2,732		2,723
Southern California Edison | Fair Value, Measurements, Recurring | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	174		172
Southern California Edison | Fair Value, Measurements, Recurring | Level 1
Assets at fair value
Derivative contracts	0		0
Other	18		28
Nuclear decommissioning trusts	2,375		2,498
Total assets	2,393		2,526
Liabilities at fair value
Derivative contracts	0		0
Total liabilities	0		0
Net assets (liabilities)	2,393		2,526
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,488		1,460
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Fixed income
Assets at fair value
Nuclear decommissioning trusts	830		947
Southern California Edison | Fair Value, Measurements, Recurring | Level 1 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	57		91
Southern California Edison | Fair Value, Measurements, Recurring | Level 2
Assets at fair value
Derivative contracts	9		0
Other	0		0
Nuclear decommissioning trusts	2,019		1,857
Total assets	2,028		1,857
Liabilities at fair value
Derivative contracts	0		22
Total liabilities	0		22
Net assets (liabilities)	2,028		1,835
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	1,902		1,776
Southern California Edison | Fair Value, Measurements, Recurring | Level 2 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	117		81
Southern California Edison | Fair Value, Measurements, Recurring | Level 3
Assets at fair value
Derivative contracts	125		163
Other	0		0
Nuclear decommissioning trusts	0		0
Total assets	125		163
Liabilities at fair value
Derivative contracts	1,295		1,311
Total liabilities	1,295		1,311
Net assets (liabilities)	(1,170)		(1,148)
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

XML

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 36	$ 37
Edison International Parent and Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 33	$ 29

XML

Fair Value Measurements (Level 3 Rollforward) (Details) - Southern California Edison - Level 3 - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value Disclosures Level 3 [Roll Forward]
Fair value of net liabilities at beginning of period	$ (1,213)	$ (976)	$ (1,148)	$ (902)
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities	43	(68)	(22)	(142)
Fair value of net liabilities at end of period	(1,170)	(1,044)	(1,170)	(1,044)
Change during the period in unrealized losses related to assets and liabilities held at the end of the period	$ 19	$ (65)	$ (54)	$ (148)

XML

Fair Value Measurements (Quantitative Information About Level 3 Fair Value Measurements) (Details) - Southern California Edison - Level 3 $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($) $ / MWh $ / MMBTU MW	Dec. 31, 2015 USD ($) $ / MWh $ / MMBTU MW
Congestion revenue rights | Market simulation model and auction prices
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 119	$ 152
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	6,289	6,289
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	24,349	24,349
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)	0.00	0.00
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)	110.44	110.44
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	1.98	1.98
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	5.72	5.72
Tolling | Option model
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 3	$ 10
Fair Value, Liabilities | $	$ 1,293	$ 1,297
Tolling | Option model | Power Prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	25.77	24.15
Expected volatility rate (as a percent)	26.00%	26.00%
Tolling | Option model | Power Prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	50.38	46.93
Expected volatility rate (as a percent)	86.00%	38.00%
Tolling | Option model | Power Prices | Weighted Average
Quantitative Information About Level 3 Measurements [Line Items]
Fair value inputs, price level ($ per MWh)	37.50	34.80
Expected volatility rate (as a percent)	30.00%	30.00%
Tolling | Option model | Gas Prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	15.00%	15.00%
Tolling | Option model | Gas Prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	41.00%	58.00%
Tolling | Option model | Gas Prices | Weighted Average
Quantitative Information About Level 3 Measurements [Line Items]
Expected volatility rate (as a percent)	20.00%	20.00%

XML

Fair Value Measurements (Fair Value of Long-Term Debt Recorded at Carrying Value) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value of Long-Term Debt Recorded at Carrying Value [Line Items]
Carrying Value1	$ 11,541	$ 11,178
Fair Value	13,521	12,252
Southern California Edison
Fair Value of Long-Term Debt Recorded at Carrying Value [Line Items]
Carrying Value1	10,503	10,539
Fair Value	$ 12,457	$ 11,592

XML

Debt and Credit Agreements (Details) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jul. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Short-term debt	$ 800,000,000			$ 695,000,000
Credit Facility Multi-Year
Debt Instrument [Line Items]
Commitment	$ 1,250,000,000.00
Weighted average interest rate (percentage)	0.69%			0.78%
Short-term debt	$ 294,000,000			$ 646,000,000
Credit Facility July 2020
Debt Instrument [Line Items]
Commitment	16,000,000
Southern California Edison
Debt Instrument [Line Items]
Short-term debt	506,000,000			49,000,000
Southern California Edison | Credit Facility Multi-Year
Debt Instrument [Line Items]
Commitment	2,750,000,000.00
Southern California Edison | Credit Facility July 2020
Debt Instrument [Line Items]
Commitment	34,000,000
Commercial paper | Southern California Edison | Credit Facility Multi-Year
Debt Instrument [Line Items]
Outstanding borrowings	$ 506,000,000			$ 49,000,000
Weighted average interest rate (percentage)	0.60%			0.51%
Letters of credit | Southern California Edison | Credit Facility Multi-Year
Debt Instrument [Line Items]
Outstanding letters of credit	$ 89,000,000
Letters of credit expiration period	12 months
Senior Notes | 2.95% Senior Notes Due 2023
Debt Instrument [Line Items]
Issuance of debt			$ 400,000,000
Stated interest rate			2.95%
Subsequent Event | Credit Facility July 2021
Debt Instrument [Line Items]
Commitment		$ 1,230,000,000.00
Subsequent Event | Southern California Edison | Credit Facility July 2021
Debt Instrument [Line Items]
Commitment		$ 2,720,000,000.00

XML

Derivative Instruments (Additional Disclosures) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Derivatives
Realized losses	$ (25,000,000)	$ (39,000,000)	$ (52,000,000)	$ (75,000,000)
Unrealized gains (losses)	72,000,000	$ (16,000,000)	8,000,000	$ (85,000,000)
Southern California Edison | Electric Utility | Economic Hedges
Derivatives
Aggregate fair value of all derivative liabilities with credit-risk-related contingent features	24,000,000		24,000,000		$ 38,000,000
Posted collateral	12,000,000		12,000,000		$ 0
Southern California Edison | Electric Utility | Economic Hedges | Payables
Derivatives
Potential amount of collateral to be posted if contingencies triggered	$ 5,000,000		$ 5,000,000

XML

Derivative Instruments (Balance Sheet Disclosures) (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	$ 65,000,000	$ 79,000,000
Long-Term, Derivative Assets	69,000,000	84,000,000
Short-Term, Derivative Liabilities	195,000,000	218,000,000
Long-Term, Derivative Liabilities	1,101,000,000	1,100,000,000
Southern California Edison
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	65,000,000	79,000,000
Long-Term, Derivative Assets	69,000,000	84,000,000
Short-Term, Derivative Liabilities	195,000,000	218,000,000
Long-Term, Derivative Liabilities	1,100,000,000	1,100,000,000
Southern California Edison | Electric Utility | Gross amounts recognized
Derivatives
Collateral that is not offset against derivative assets	12,000,000	0
Southern California Edison | Commodity Contracts | Other current liabilities
Derivatives
Collateral that is not offset against derivative assets	(4,000,000)
Southern California Edison | Commodity Contracts | Other current assets
Derivatives
Collateral that is not offset against derivative assets		31,000,000
Southern California Edison | Commodity Contracts | Electric Utility
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	65,000,000	79,000,000
Long-Term, Derivative Assets	69,000,000	84,000,000
Derivative Assets, Subtotal	134,000,000	163,000,000
Short-Term, Derivative Liabilities	195,000,000	218,000,000
Long-Term, Derivative Liabilities	1,100,000,000	1,100,000,000
Derivative Liabilities, Subtotal	1,295,000,000	1,318,000,000
Net Liability	1,161,000,000	1,155,000,000
Southern California Edison | Commodity Contracts | Electric Utility | Gross amounts recognized
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	66,000,000	81,000,000
Long-Term, Derivative Assets	69,000,000	84,000,000
Derivative Assets, Subtotal	135,000,000	165,000,000
Short-Term, Derivative Liabilities	196,000,000	235,000,000
Long-Term, Derivative Liabilities	1,100,000,000	1,100,000,000
Derivative Liabilities, Subtotal	1,296,000,000	1,335,000,000
Net Liability	1,161,000,000	1,170,000,000
Southern California Edison | Commodity Contracts | Electric Utility | Gross amounts offset in the consolidated balance sheets
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	(1,000,000)	(2,000,000)
Long-Term, Derivative Assets	0	0
Derivative Assets, Subtotal	(1,000,000)	(2,000,000)
Short-Term, Derivative Liabilities	(1,000,000)	(2,000,000)
Long-Term, Derivative Liabilities	0	0
Derivative Liabilities, Subtotal	(1,000,000)	(2,000,000)
Net Liability	0	0
Southern California Edison | Commodity Contracts | Electric Utility | Cash collateral posted
Fair Value of Derivative Instruments
Short-Term, Derivative Assets	0	0
Long-Term, Derivative Assets	0	0
Derivative Assets, Subtotal	0	0
Short-Term, Derivative Liabilities	0	(15,000,000)
Long-Term, Derivative Liabilities	0	0
Derivative Liabilities, Subtotal	0	(15,000,000)
Net Liability	$ 0	$ (15,000,000)

XML

Derivative Instruments (Notional Values) (Details) - Southern California Edison - Electric Utility - Economic Hedges GWh in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016 Bcfe GWh	Dec. 31, 2015 Bcfe GWh
Electricity options, swaps and forwards (GWh)
Derivatives
Notional volumes of derivative instruments	4,980	6,221
Natural gas options, swaps and forwards (Bcf)
Derivatives
Notional volumes of derivative instruments | Bcfe	4	32
Congestion revenue rights (GWh)
Derivatives
Notional volumes of derivative instruments	80,094	109,740
Tolling arrangements (GWh)
Derivatives
Notional volumes of derivative instruments	65,998	70,663

XML

Income Taxes (Tax Rate Reconciliation) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Tax Disclosure [Line Items]
Income from continuing operations before income taxes	$ 259	$ 412	$ 591	$ 837
Provision for income tax at federal statutory rate of 35%	91	144	207	293
Increase in income tax from:
State tax, net of federal benefit	4	5	11	16
Property-related	(138)	(69)	(217)	(129)
Change related to uncertain tax positions	2	(77)	1	(62)
Other	(6)	3	(11)	(5)
Total income tax (benefit) expense from continuing operations	$ (47)	$ 6	$ (9)	$ 113
Effective tax rate	(18.10%)	1.50%	(1.50%)	13.50%
Federal statutory rate	35.00%	35.00%	35.00%	35.00%
Southern California Edison
Income Tax Disclosure [Line Items]
Income from continuing operations before income taxes	$ 317	$ 419	$ 683	$ 860
Provision for income tax at federal statutory rate of 35%	111	147	239	301
Increase in income tax from:
State tax, net of federal benefit	6	2	15	16
Property-related	(138)	(69)	(217)	(129)
Change related to uncertain tax positions	(1)	(75)	(2)	(65)
Other	(7)	2	(14)	(8)
Total income tax (benefit) expense from continuing operations	$ (29)	$ 7	$ 21	$ 115
Effective tax rate	(9.10%)	1.70%	3.10%	13.40%
Federal statutory rate	35.00%	35.00%	35.00%	35.00%
Tax Years 2012 to 2014 | Internal Revenue Service (IRS) | Southern California Edison
Increase in income tax from:
Tax liability	$ 79
Tax adjustments, pre tax	$ 133

XML

Income Taxes (Textual) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2016	Jun. 30, 2016	Jun. 30, 2015
Southern California Edison
Income Tax Disclosure [Line Items]
Reduction in base revenue requirement balancing account	$ 234
IRS Examination | Tax Years 2010 to 2012
Income Tax Disclosure [Line Items]
Tax liability			$ 94
IRS Examination | Southern California Edison | Tax Years 2012 to 2014
Income Tax Disclosure [Line Items]
Tax liability		$ (79)
Tax adjustments, pre tax		$ 133
IRS Examination | Southern California Edison | Tax Years 2010 to 2012
Income Tax Disclosure [Line Items]
Tax liability			$ 100

XML

Compensation and Benefit Plans (Expense Components) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Plans
Pension and Other Postretirement Benefits
Service cost	$ 39	$ 35	$ 78	$ 70
Interest cost	44	42	88	83
Expected return on plan assets	(56)	(57)	(112)	(114)
Amortization of prior service cost	1	1	2	2
Amortization of net loss	9	9	18	18
Expense under accounting standards	37	30	74	59
Regulatory adjustment	(9)	(1)	(18)	(2)
Total expense recognized	28	29	56	57
Net loss reclassified	3	4	6	7
Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Service cost	10	12	20	24
Interest cost	26	28	52	57
Expected return on plan assets	(28)	(29)	(56)	(57)
Amortization of prior service cost	(1)	(3)	(2)	(6)
Amortization of net loss	0	6	0	12
Expense under accounting standards	7	14	14	30
Southern California Edison | Pension Plans
Pension and Other Postretirement Benefits
Service cost	38	34	76	69
Interest cost	41	37	82	75
Expected return on plan assets	(53)	(54)	(106)	(107)
Amortization of prior service cost	1	2	2	3
Amortization of net loss	8	8	16	15
Expense under accounting standards	35	27	70	55
Regulatory adjustment	(9)	(1)	(18)	(2)
Total expense recognized	26	26	52	53
Net loss reclassified	1	2	3	4
Southern California Edison | Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Service cost	10	12	20	24
Interest cost	26	28	52	56
Expected return on plan assets	(28)	(28)	(56)	(56)
Amortization of prior service cost	(1)	(3)	(2)	(6)
Amortization of net loss	0	5	0	11
Expense under accounting standards	$ 7	$ 14	$ 14	$ 29

XML

Compensation and Benefit Plans (Textual) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Pension Plans
Pension and Other Postretirement Benefits
Employer contributions	$ 47
Estimated future contributions in remainder of year	73
Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Employer contributions	17
Estimated future contributions in remainder of year	16
Southern California Edison | Pension Plans
Pension and Other Postretirement Benefits
Employer contributions	37
Estimated future contributions in remainder of year	$ 58

XML

Compensation and Benefit Plans (Workforce Reduction) (Details) - Southern California Edison - Employee severance $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Restructuring Reserve [Roll Forward]
Balance at January 1, 2016	$ 22
Additions	13
Payments	(23)
Balance at June 30, 2016	$ 12

XML

Investments (Amortized Cost and Fair Value of Nuclear Decommissioning Trusts) (Details) - Southern California Edison - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	$ 2,810	$ 2,917
Fair Value	4,344	4,331
Stocks
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	329	304
Fair Value	1,488	1,460
Municipal bonds
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	675	691
Fair Value	854	840
U.S. government and agency securities
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	1,002	1,070
Fair Value	1,107	1,128
Corporate bonds
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	683	708
Fair Value	771	755
Short-term investments and receivables/payables
Nuclear Decommissioning Trusts Disclosures
Amortized Cost	121	144
Fair Value	124	148
Repurchase agreement	$ 85	$ 81

XML

Investments (Summary of Changes in Fair Value of the Nuclear Decommissioning Trusts) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period			$ 4,331
Balance at end of period	$ 4,344		4,344
Southern California Edison
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period	4,290	$ 4,896	4,331	$ 4,799
Gross realized gains	22	5	75	32
Gross realized losses	(1)	(3)	(4)	(5)
Unrealized gains (losses), net	72	(71)	113	(27)
Other-than-temporary impairments	(8)	(8)	(33)	(12)
Interest and dividends	32	32	60	60
Contributions	0	0	0	7
Income taxes	(24)	(14)	(42)	(14)
Decommissioning disbursements	(38)	0	(154)	0
Administrative expenses and other	(1)	(1)	(2)	(4)
Balance at end of period	$ 4,344	$ 4,836	$ 4,344	$ 4,836

XML

Investments (Textual) (Details) - Southern California Edison - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Other Investments [Line Items]
Unrealized holding gains, net of losses	$ 1,500	$ 1,400
Deferred income taxes related to unrealized gains	375
Nuclear decommissioning trusts	$ 4,000

XML

Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets	$ 478	$ 560
Regulatory assets	7,792	7,512
Environmental remediation
Regulatory Assets [Line Items]
Regulatory assets	128	129
Southern California Edison
Regulatory Assets [Line Items]
Regulatory assets	478	560
Regulatory assets	7,792	7,512
Total regulatory assets	8,270	8,072
Southern California Edison | Regulatory balancing accounts
Regulatory Assets [Line Items]
Regulatory assets	309	382
Regulatory assets	49	36
Southern California Edison | Energy derivatives
Regulatory Assets [Line Items]
Regulatory assets	135	159
Regulatory assets	1,041	1,027
Southern California Edison | Other
Regulatory Assets [Line Items]
Regulatory assets	34	19
Regulatory assets	271	288
Southern California Edison | Deferred income taxes, net
Regulatory Assets [Line Items]
Regulatory assets	4,176	3,757
Southern California Edison | Pensions and other postretirement benefits
Regulatory Assets [Line Items]
Regulatory assets	836	849
Southern California Edison | Unamortized investments, net
Regulatory Assets [Line Items]
Regulatory assets	156	182
Southern California Edison | San Onofre
Regulatory Assets [Line Items]
Regulatory assets	942	1,043
Southern California Edison | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets	$ 193	$ 201

XML

Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory liabilities	$ 1,072	$ 1,128
Regulatory liabilities	6,017	5,676
Southern California Edison
Regulatory Liabilities [Line Items]
Regulatory liabilities	1,072	1,128
Regulatory liabilities	6,017	5,676
Total regulatory liabilities	7,089	6,804
Southern California Edison | Regulatory balancing accounts
Regulatory Liabilities [Line Items]
Regulatory liabilities	1,050	1,106
Regulatory liabilities	1,392	1,314
Southern California Edison | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities	22	22
Regulatory liabilities	60	79
Southern California Edison | Costs of removal
Regulatory Liabilities [Line Items]
Regulatory liabilities	2,825	2,781
Southern California Edison | Recoveries in excess of ARO liabilities
Regulatory Liabilities [Line Items]
Regulatory liabilities	$ 1,740	$ 1,502

XML

Regulatory Assets and Liabilities (Schedule of Net Regulatory Balancing Accounts) (Details) - Southern California Edison - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Regulatory balancing accounts | Energy resource recovery account
Regulatory Assets and Liabilities
Net liability	$ (252)	$ (439)
Regulatory balancing accounts | New system generation balancing account
Regulatory Assets and Liabilities
Net liability	(195)	(171)
Refunds of excess revenue | Significant Components
Regulatory Assets and Liabilities
Net liability	(2,084)	(2,002)
Refunds of excess revenue | Public purpose programs and energy efficiency programs
Regulatory Assets and Liabilities
Net liability	(828)	(683)
Refunds of excess revenue | Tax accounting memorandum account and pole loading balancing account
Regulatory Assets and Liabilities
Net liability	(68)	(248)
Refunds of excess revenue | Base rate recovery balancing account
Regulatory Assets and Liabilities
Net liability	(535)	(319)
Refunds of excess revenue | Greenhouse gas auction revenue
Regulatory Assets and Liabilities
Net liability	(4)	(75)
Refunds of excess revenue | FERC balancing accounts
Regulatory Assets and Liabilities
Net liability	40	74
Refunds of excess revenue | Department of Energy litigation memorandum account
Regulatory Assets and Liabilities
Net liability	(122)	0
Refunds of excess revenue | Other
Regulatory Assets and Liabilities
Net liability	$ (120)	$ (141)

XML

Commitments and Contingencies (Details)		1 Months Ended				6 Months Ended		12 Months Ended
	Jul. 14, 2016 USD ($)	Apr. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Oct. 31, 2013 USD ($)	Jun. 30, 2010 USD ($)	Jun. 30, 2016 USD ($) site invoice	Jun. 30, 2015 USD ($)	Dec. 31, 2012 USD ($)	Sep. 30, 2015 USD ($)
Schedule Of Commitments And Contingencies [Line Items]
Damages sought			$ 39,900,000
Nuclear Insurance
Schedule Of Commitments And Contingencies [Line Items]
Federal limit on public liability claims from nuclear incident, approximate						$ 13,400,000,000
Southern California Edison
Schedule Of Commitments And Contingencies [Line Items]
Damages sought					$ 112,000,000
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						$ 130,000,000
Immaterial sites for environmental remediation (in number of sites) | site						39
Environmental remediation liability						$ 134,000,000
Regulatory assets related to environmental remediation						128,000,000
Portion of recorded liability recoverable from incentive mechanism						$ 46,000,000
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						$ 82,000,000
Environmental remediation costs to be recovered (as a percent)						100.00%
Amount that cleanup costs could exceed recorded liability for identified material sites						$ 165,000,000
Amount that cleanup costs could exceed recorded liability for immaterial sites						$ 7,000,000
Maximum expected period for cleanup of identified sites (in years)						30 years
Remediation cost estimates (period)						4 years
Expected annual environmental remediation costs, low end of range						$ 7,000,000
Expected annual environmental remediation costs, high end of range						23,000,000
Environmental remediation costs						1,000,000	$ 3,000,000
Threshold for wildfire claims (new lines for additional coverage)						910,000,000
Increase in self-insurance						90,000,000
Combined threshold for wildfire claims						1,000,000,000
Self-insured retention per wildfire occurrence						10,000,000
Damage award		$ 124,000,000
Southern California Edison | San Onofre
Schedule Of Commitments And Contingencies [Line Items]
Minimum liability for environmental remediation for material sites						$ 79,000,000
Southern California Edison | San Onofre | Mitsubishi Heavy Industries Ltd
Schedule Of Commitments And Contingencies [Line Items]
Damages sought				$ 4,000,000,000
Number of invoices for reimbursement | invoice						7
Invoiced amount for reimbursement						$ 149,000,000
Invoiced amount paid for reimbursement						$ 45,000,000
Share of invoice paid								$ 35,000,000
Southern California Edison | San Onofre | Mitsubishi Heavy Industries Ltd
Schedule Of Commitments And Contingencies [Line Items]
Ratepayer allocation of recovery from recoveries						50.00%
Entity allocation of recovery from recoveries						50.00%
Ratepayer allocation of recovery from recoveries, initial amount of settlement						$ 282,000,000
Southern California Edison | San Onofre | Replacement Steam Generators
Schedule Of Commitments And Contingencies [Line Items]
Warranty period						20 years
Southern California Edison | Nuclear Insurance
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
Mitsubishi Heavy Industries Ltd | San Onofre
Schedule Of Commitments And Contingencies [Line Items]
Maximum liability per purchase agreement for damages						138,000,000
Asserted counterclaim				$ 41,000,000
SCE and other owners of San Onofre and Palo Verde
Schedule Of Commitments And Contingencies [Line Items]
Damages sought					$ 142,000,000
Damage award		$ 162,000,000
SCE and other owners of San Onofre and Palo Verde | Nuclear Insurance | San Onofre and Palo Verde
Schedule Of Commitments And Contingencies [Line Items]
Loss limit, property damage insurance, federal minimum requirement						1,060,000,000
Maximum
Schedule Of Commitments And Contingencies [Line Items]
Minimum liability for environmental remediation for immaterial sites									$ 74,500,000
Maximum | Subsequent Event
Schedule Of Commitments And Contingencies [Line Items]
Penalties per day per violation	$ 50,000
Minimum | Subsequent Event
Schedule Of Commitments And Contingencies [Line Items]
Penalties per day per violation	$ 500
Minimum | Southern California Edison
Schedule Of Commitments And Contingencies [Line Items]
Minimum liability for environmental remediation for immaterial sites						$ 4,000,000

XML

Preferred and Preference Stock of SCE (Details) - Southern California Edison	3 Months Ended
	Mar. 31, 2016 USD ($) $ / shares shares
Series K Preferred Stock
Preferred and Preference Stock of Utility
Preferred stock issued	$ 300,000,000
Preference stock dividend rate (percent)	5.45%
Shares issued (in shares) | shares	120,004
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Series D Preferred Stock
Preferred and Preference Stock of Utility
Redemption of preference stock	$ 125,000,000

XML

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accumulated Other Comprehensive Loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ (54)	$ (59)	$ (56)	$ (58)
Pension and PBOP – net loss:
Ending Balance	(53)	(56)	(53)	(56)
Accumulated Other Comprehensive Loss | Southern California Edison
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(21)	(27)	(22)	(28)
Pension and PBOP – net loss:
Ending Balance	(20)	(26)	(20)	(26)
Accumulated Defined Benefit Plans Adjustment
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	0	(1)	0	(4)
Reclassified from accumulated other comprehensive loss	1	4	3	6
Change	1	3	3	2
Accumulated Defined Benefit Plans Adjustment | Southern California Edison
Pension and PBOP – net loss:
Other comprehensive loss before reclassifications	0	(1)	0	(1)
Reclassified from accumulated other comprehensive loss	1	2	2	3
Change	$ 1	$ 1	$ 2	$ 2

XML

Interest and Other Income and Other Expenses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
SCE interest and other income:
Interest and other income	$ 33	$ 43	$ 65	$ 82
SCE other expenses:
Total Edison International other expenses	11	17	19	24
Southern California Edison
SCE interest and other income:
Equity allowance for funds used during construction	19	21	42	42
Increase in cash surrender value of life insurance policies	11	7	17	17
Interest income	2	2	3	3
Other	1	1	3	2
Total SCE interest and other income	33	31	65	64
Interest and other income	33	31	65	64
SCE other expenses:
Civic, political and related activities and donations	8	9	12	14
Other	3	8	7	10
Total SCE other expenses	11	17	19	24
Total Edison International other expenses	11	17	19	24
Edison International Parent and Other
SCE interest and other income:
Other income of Edison International Parent and Other	$ 0	$ 12	$ 0	$ 18

XML

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Cash payments for interest and taxes
Interest, net of amounts capitalized		$ 228	$ 230
Tax payments, net		12	3
Convertible Debt [Abstract]
Pollution-control bonds redeemed (2.875%)		0	(203)
Pollution-control bonds issued (1.875%)		0	203
Common stock
Dividends declared but not paid
Dividends declared but not paid	$ 136	156	136
Preferred and preference stock
Dividends declared but not paid
Dividends declared but not paid	18	12	18
Southern California Edison
Cash payments for interest and taxes
Interest, net of amounts capitalized		221	222
Tax payments, net		32	125
Convertible Debt [Abstract]
Pollution-control bonds redeemed (2.875%)		0	(203)
Pollution-control bonds issued (1.875%)		0	203
Accrued capital expenditures		338	393
Reduction in lease obligation	147
Southern California Edison | Common stock
Dividends declared but not paid
Dividends declared but not paid	147	0	147
Southern California Edison | Preferred and preference stock
Dividends declared but not paid
Dividends declared but not paid	$ 18	$ 12	$ 18
2.875% Pollution-Control Bonds
Convertible Debt [Abstract]
Interest rate on converted debt		2.875%	2.875%
2.875% Pollution-Control Bonds | Southern California Edison
Convertible Debt [Abstract]
Interest rate on converted debt		2.875%	2.875%
1.875% Pollution-Control Bonds Due in 2029
Convertible Debt [Abstract]
Interest rate on converted debt		1.875%	1.875%
1.875% Pollution-Control Bonds Due in 2029 | Southern California Edison
Convertible Debt [Abstract]
Interest rate on converted debt		1.875%	1.875%