Edison International (EIX) 10-K 21 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 17, 2017	Jun. 30, 2016
Entity Information [Line Items]
Entity Registrant Name	EDISON INTERNATIONAL
Entity Central Index Key	827,052
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		325,811,206
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 25,300,000,000
Southern California Edison Company
Entity Information [Line Items]
Entity Registrant Name	SOUTHERN CALIFORNIA EDISON CO
Entity Central Index Key	92,103
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		434,888,104
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Total operating revenue	$ 11,869	$ 11,524	$ 13,413
Purchased power and fuel	4,527	4,266	5,593
Operation and maintenance	2,868	2,990	3,149
Depreciation, decommissioning and amortization	2,007	1,919	1,720
Property and other taxes	354	336	322
Impairment and other charges	21	5	157
Total operating expenses	9,777	9,516	10,941
Operating income (loss)	2,092	2,008	2,472
Interest and other income	123	174	147
Interest expense	(581)	(555)	(560)
Other expenses	(44)	(59)	(80)
Income from continuing operations before income taxes	1,590	1,568	1,979
Income tax expense	177	486	443
Income from continuing operations	1,413	1,082	1,536
Income from discontinued operations, net of tax	12	35	185
Net income	1,425	1,117	1,721
Preferred and preference stock dividend requirements of utility	123	113	112
Other noncontrolling interests	(9)	(16)	(3)
Net income from continuing operations available to common shareholders	1,311	1,020	1,612
Basic earnings per common share attributable to Edison International common shareholders:
Income from continuing operations, net of tax	1,299	985	1,427
Income from discontinued operations, net of tax	12	35	185
Net income from continuing operations available to common shareholders	$ 1,311	$ 1,020	$ 1,612
Basic earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding	326	326	326
Continuing operations (in dollars per share)	$ 3.99	$ 3.02	$ 4.38
Discontinued operations (in dollars per share)	0.03	0.11	0.57
Total (in dollars per share)	$ 4.02	$ 3.13	$ 4.95
Diluted earnings per common share attributable to Edison International common shareholders:
Weighted-average shares of common stock outstanding, including effect of dilutive securities	330	329	329
Continuing operations (in dollars per share)	$ 3.94	$ 2.99	$ 4.33
Discontinued operations (in dollars per share)	0.03	0.11	0.56
Total (in dollars per share)	3.97	3.10	4.89
Dividends declared per common share (in dollars per share)	$ 1.9825	$ 1.7325	$ 1.4825
Southern California Edison Company
Total operating revenue	$ 11,830	$ 11,485	$ 13,380
Purchased power and fuel	4,527	4,266	5,593
Operation and maintenance	2,737	2,890	3,057
Depreciation, decommissioning and amortization	1,998	1,915	1,720
Property and other taxes	351	334	318
Impairment and other charges	0	0	163
Total operating expenses	9,613	9,405	10,851
Operating income (loss)	2,217	2,080	2,529
Interest and other income	123	123	122
Interest expense	(541)	(526)	(533)
Other expenses	(44)	(59)	(79)
Income from continuing operations before income taxes	1,755	1,618	2,039
Income tax expense	256	507	474
Net income	1,499	1,111	1,565
Preferred and preference stock dividend requirements of utility	123	113	112
Net income from continuing operations available to common shareholders	1,376	998	1,453
Basic earnings per common share attributable to Edison International common shareholders:
Net income from continuing operations available to common shareholders	$ 1,376	$ 998	$ 1,453

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income	$ 1,425	$ 1,117	$ 1,721
Pension and postretirement benefits other than pensions:
Net gain (loss) arising during the period plus amortization included in net income	2	1	(47)
Prior service cost arising during the period plus amortization included in net income	0	1	0
Other	1	0	2
Other comprehensive income (loss), net of tax	3	2	(45)
Comprehensive income	1,428	1,119	1,676
Less: Comprehensive income attributable to noncontrolling interests	114	97	109
Comprehensive income	1,314	1,022	1,567
Southern California Edison Company
Net income	1,499	1,111	1,565
Pension and postretirement benefits other than pensions:
Net gain (loss) arising during the period plus amortization included in net income	1	5	(19)
Prior service cost arising during the period plus amortization included in net income	0	1	0
Other	1	0	2
Other comprehensive income (loss), net of tax	2	6	(17)
Comprehensive income	$ 1,501	$ 1,117	$ 1,548

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 96	$ 161
Receivables, less allowances for uncollectible accounts	714	771
Accrued unbilled revenue	370	565
Inventory	239	267
Derivative assets	73	79
Regulatory assets	350	560
Other current assets	281	251
Total current assets	2,123	2,654
Nuclear decommissioning trusts	4,242	4,331
Other investments	83	203
Total investments	4,325	4,534
Utility property, plant and equipment, less accumulated depreciation and amortization	36,806	34,945
Nonutility property, plant and equipment, less accumulated depreciation	194	140
Total property, plant and equipment	37,000	35,085
Derivative assets	1	84
Regulatory assets	7,455	7,512
Other long-term assets	415	360
Total long-term assets	7,871	7,956
Total assets	51,319	50,229
LIABILITIES AND EQUITY
Short-term debt	1,307	695
Current portion of long-term debt	981	295
Accounts payable	1,342	1,310
Accrued taxes	50	72
Customer deposits	269	242
Derivative liabilities	216	218
Regulatory liabilities	756	1,128
Other current liabilities	991	967
Total current liabilities	5,912	4,927
Long-term debt	10,175	10,883
Deferred income taxes and credits	8,327	7,480
Derivative liabilities	941	1,100
Pensions and benefits	1,354	1,759
Asset retirement obligations	2,590	2,764
Regulatory liabilities	5,726	5,676
Other deferred credits and other long-term liabilities	2,102	2,246
Total deferred credits and other liabilities	21,040	21,025
Total liabilities	37,127	36,835
Commitments and contingencies (Note 11)
Redeemable noncontrolling interest	5	6
Common stock, no par value	2,505	2,484
Accumulated other comprehensive loss	(53)	(56)
Retained earnings	9,544	8,940
Total common shareholders' equity	11,996	11,368
Noncontrolling interests – preferred and preference stock of utility	2,191	2,020
Total equity	14,187	13,388
Total liabilities and equity	51,319	50,229
Southern California Edison Company
ASSETS
Cash and cash equivalents	39	26
Receivables, less allowances for uncollectible accounts	699	724
Accrued unbilled revenue	369	564
Inventory	239	256
Derivative assets	73	79
Regulatory assets	350	560
Other current assets	262	234
Total current assets	2,031	2,443
Nuclear decommissioning trusts	4,242	4,331
Other investments	50	168
Total investments	4,292	4,499
Utility property, plant and equipment, less accumulated depreciation and amortization	36,806	34,945
Nonutility property, plant and equipment, less accumulated depreciation	75	73
Total property, plant and equipment	36,881	35,018
Derivative assets	1	84
Regulatory assets	7,455	7,512
Other long-term assets	231	239
Total long-term assets	7,687	7,835
Total assets	50,891	49,795
LIABILITIES AND EQUITY
Short-term debt	769	49
Current portion of long-term debt	579	79
Accounts payable	1,344	1,299
Accrued taxes	45	46
Customer deposits	269	242
Derivative liabilities	216	218
Regulatory liabilities	756	1,128
Other current liabilities	729	760
Total current liabilities	4,707	3,821
Long-term debt	9,754	10,460
Deferred income taxes and credits	9,886	9,073
Derivative liabilities	941	1,100
Pensions and benefits	896	1,284
Asset retirement obligations	2,586	2,762
Regulatory liabilities	5,726	5,676
Other deferred credits and other long-term liabilities	1,912	1,947
Total deferred credits and other liabilities	21,947	21,842
Total liabilities	36,408	36,123
Commitments and contingencies (Note 11)
Common stock, no par value	2,168	2,168
Additional paid-in capital	657	652
Accumulated other comprehensive loss	(20)	(22)
Retained earnings	9,433	8,804
Total common shareholders' equity	12,238	11,602
Noncontrolling interests – preferred and preference stock of utility	2,245	2,070
Total equity	14,483	13,672
Total liabilities and equity	$ 50,891	$ 49,795

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Receivables, allowances for uncollectible accounts	$ 62	$ 62
Utility property, plant and equipment, accumulated depreciation	9,000	8,548
Nonutility property, plant and equipment, accumulated depreciation	$ 99	$ 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 Company
Receivables, allowances for uncollectible accounts	$ 61	$ 62
Utility property, plant and equipment, accumulated depreciation	9,000	8,548
Nonutility property, plant and equipment, accumulated depreciation	$ 89	$ 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

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities:
Net income	$ 1,425	$ 1,117	$ 1,721
Income (loss) from discontinued operations, net of tax	12	35	185
Income from continuing operations	1,413	1,082	1,536
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	2,098	2,005	1,815
Allowance for equity during construction	(74)	(87)	(65)
Impairment and other charges	0	5	157
Deferred income taxes and investment tax credits	190	449	522
Other	20	(28)	20
Nuclear decommissioning trusts	(179)	(428)	39
EME settlement payments, net of insurance proceeds	(209)	(176)	(225)
Changes in operating assets and liabilities:
Receivables	52	49	64
Inventory	8	14	(25)
Accounts payable	35	8	14
Prepaid and accrued taxes	(6)	(28)	(100)
Other current assets and liabilities	211	(24)	(103)
Derivative assets and liabilities, net	13	45	(40)
Regulatory assets and liabilities, net	(292)	1,729	(358)
Other noncurrent assets and liabilities	(24)	(106)	(3)
Net cash provided by operating activities	3,256	4,509	3,248
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs	397	1,420	494
Long-term debt matured or repurchased	(220)	(762)	(607)
Preference stock issued, net	294	319	269
Preference stock redeemed	(125)	(325)	0
Short-term debt financing, net	611	(572)	1,079
Dividends to noncontrolling interests	(123)	(116)	(111)
Dividends paid	(626)	(544)	(463)
Other	(113)	(8)	(16)
Net cash (used in) provided by financing activities	95	(588)	645
Cash flows from investing activities:
Capital expenditures	(3,734)	(4,225)	(3,906)
Proceeds from sale of nuclear decommissioning trust investments	3,212	3,506	2,617
Purchases of nuclear decommissioning trust investments	(3,033)	(3,132)	(2,661)
Life insurance policy loans proceeds	140	0	0
Other	(1)	(41)	43
Net cash used in investing activities	(3,416)	(3,892)	(3,907)
Net (decrease) increase in cash and cash equivalents	(65)	29	(14)
Cash and cash equivalents, beginning of year	161	132	146
Cash and cash equivalents, end of year	96	161	132
Southern California Edison Company
Cash flows from operating activities:
Net income	1,499	1,111	1,565
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, decommissioning and amortization	2,085	1,996	1,810
Allowance for equity during construction	(74)	(87)	(65)
Impairment and other charges	0	0	163
Deferred income taxes and investment tax credits	88	308	462
Other	9	14	11
Nuclear decommissioning trusts	(179)	(428)	39
Changes in operating assets and liabilities:
Receivables	25	25	64
Inventory	(3)	19	(19)
Accounts payable	45	30	12
Prepaid and accrued taxes	(16)	(16)	129
Other current assets and liabilities	185	(42)	(107)
Derivative assets and liabilities, net	13	45	(40)
Regulatory assets and liabilities, net	(292)	1,729	(358)
Other noncurrent assets and liabilities	138	(80)	(6)
Net cash provided by operating activities	3,523	4,624	3,660
Cash flows from financing activities:
Long-term debt issued or remarketed, net of discount and issuance costs	0	1,413	498
Long-term debt matured or repurchased	(217)	(761)	(607)
Preference stock issued, net	294	319	269
Preference stock redeemed	(125)	(325)	0
Short-term debt financing, net	719	(619)	490
Dividends paid	(824)	(874)	(489)
Other	(66)	35	20
Net cash (used in) provided by financing activities	(219)	(812)	181
Cash flows from investing activities:
Capital expenditures	(3,633)	(4,210)	(3,857)
Proceeds from sale of nuclear decommissioning trust investments	3,212	3,506	2,617
Purchases of nuclear decommissioning trust investments	(3,033)	(3,132)	(2,661)
Life insurance policy loans proceeds	140	0	0
Other	23	12	44
Net cash used in investing activities	(3,291)	(3,824)	(3,857)
Net (decrease) increase in cash and cash equivalents	13	(12)	(16)
Cash and cash equivalents, beginning of year	26	38	54
Cash and cash equivalents, end of year	$ 39	$ 26	$ 38

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Discounts and issuance costs of long term debt	$ 7	$ 17	$ 6
Southern California Edison Company
Discounts and issuance costs of long term debt		$ 17	$ 2

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Southern California Edison Company	Common Stock	Common StockSouthern California Edison Company	Additional Paid-in CapitalSouthern California Edison Company	Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive LossSouthern California Edison Company	Retained Earnings	Retained EarningsSouthern California Edison Company	Subtotal	Preferred and Preference Stock	Preferred and Preference StockSouthern California Edison Company
Balance, at the beginning of the period at Dec. 31, 2013	$ 11,691	$ 12,138	$ 2,403	$ 2,168	$ 592	$ (13)	$ (11)	$ 7,548	$ 7,594	$ 9,938	$ 1,753	$ 1,795
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,724	1,565						1,612	1,565	1,612	112
Other comprehensive income (loss)	(45)	(17)				(45)	(17)			(45)
Dividends declared on common stock	(483)	(525)						(483)	(525)	(483)
Dividends declared on preferred and preference stock		(112)							(112)
Dividends and distributions to noncontrolling interests and other	(112)										(112)
Stock-based compensation and other	(89)	(44)	15		20			(104)	(64)	(89)
Noncash stock-based compensation and other	27	8	27		12				(4)	27
Issuance of preference stock	269	269			(6)						269	275
Balance, at the end of the period at Dec. 31, 2014	12,982	13,282	2,445	2,168	618	(58)	(28)	8,573	8,454	10,960	2,022	2,070
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,133	1,111						1,020	1,111	1,020	113
Other comprehensive income (loss)	2	6				2	6			2
Dividends declared on common stock	(564)	(611)						(564)	(611)	(564)
Dividends declared on preferred and preference stock		(113)							(113)
Dividends and distributions to noncontrolling interests and other	(113)										(113)
Stock-based compensation and other	(70)	(10)	15		23			(85)	(33)	(70)
Noncash stock-based compensation and other	24	13	24		13					24
Issuance of preference stock	319	319			(6)						319	325
Redemption of preference stock	(325)	(325)			4			(4)	(4)	(4)	(321)	(325)
Balance, at the end of the period at Dec. 31, 2015	13,388	13,672	2,484	2,168	652	(56)	(22)	8,940	8,804	11,368	2,020	2,070
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,434	1,499						1,311	1,499	1,311	123
Other comprehensive income (loss)	3	2				3	2			3
Dividends declared on common stock	(646)	(701)						(646)	(701)	(646)
Dividends declared on preferred and preference stock		(123)							(123)
Dividends and distributions to noncontrolling interests and other	(123)										(123)
Stock-based compensation and other	(60)	(44)	(1)					(59)	(44)	(60)
Noncash stock-based compensation and other	22	9	22		9					22
Issuance of preference stock	294	294			(6)						294	300
Redemption of preference stock	(125)	(125)			2			(2)	(2)	(2)	(123)	(125)
Balance, at the end of the period at Dec. 31, 2016	$ 14,187	$ 14,483	$ 2,505	$ 2,168	$ 657	$ (53)	$ (20)	$ 9,544	$ 9,433	$ 11,996	$ 2,191	$ 2,245

Consolidated Statements of Cha9

Consolidated Statements of Changes in Equity (Parenthetical) - $ / shares	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Dividends declared per common share (in dollars per share)	$ 0.5425	$ 0.4800	$ 0.4800	$ 0.4800	$ 0.48	$ 0.4175	$ 0.4175	$ 0.4175	$ 1.9825	$ 1.7325	$ 1.4825

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 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 holding company for subsidiaries engaged in pursuing competitive business opportunities across energy services and distributed solar for commercial and industrial customers. Such business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutility subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements. Edison International's and SCE's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission ("CPUC") and the Federal Energy Regulatory Commission ("FERC"). SCE applies authoritative guidance for rate-regulated enterprises to the portion of its operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. SCE assesses, at the end of each reporting period, whether regulatory assets are probable of future recovery. See Note 10 for composition of regulatory assets and liabilities. The preparation of financial statements in conformity with United States generally accepted accounting principles ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates. Cash Equivalents Cash equivalents includes investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less. The cash equivalents were as follows: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Money market funds $ 41 $ 37 $ 18 $ 8 Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Book balances reclassified to accounts payable $ 138 $ 162 $ 136 $ 158 Allowance for Uncollectible Accounts Allowances for uncollectible accounts are provided based upon a variety of factors, including historical amounts written-off, current economic conditions and assessment of customer collectability. Inventory SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at average cost. Emission Allowances SCE is allocated greenhouse gas ("GHG") allowances annually which it is then required to sell into quarterly auctions. GHG proceeds from the auctions are recorded as a regulatory liability to be refunded to customers. SCE purchases GHG allowances in quarterly auctions or from counterparties to satisfy its GHG emission compliance obligations and recovers such costs of GHG allowances from customers. GHG allowances held for use are classified as "Other current assets" on the consolidated balance sheets and are stated, similar to an inventory method, at the lower of weighted-average cost or market. SCE had GHG allowances of $113 million and $79 million at December 31, 2016 and 2015 , respectively. GHG emission obligations were $95 million and $86 million at December 31, 2016 and 2015 , respectively and are classified as "Other current liabilities" on the consolidated balance sheets. Property, Plant and Equipment SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, pension and benefits, and property taxes are capitalized as part of plant additions. The CPUC authorizes a rate for each of the indirect costs which are allocated to each project based on either labor or total costs. Estimated useful lives (authorized by the CPUC) and weighted-average useful lives of SCE's property, plant and equipment, are as follows: Estimated Useful Lives Weighted-Average Useful Lives Generation plant 10 years to 57 years 38 years Distribution plant 20 years to 60 years 43 years Transmission plant 40 years to 65 years 53 years General plant and other 5 years to 60 years 22 years Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. Depreciation expense was $1.52 billion , $1.42 billion and $1.33 billion for 2016 , 2015 and 2014 , respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.8% , 3.9% and 4.0% for 2016 , 2015 and 2014 , respectively. Replaced or retired property costs are charged to accumulated depreciation. Nuclear fuel for the Palo Verde Nuclear Power Plant ("Palo Verde") is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. Nuclear fuel is amortized using the units of production method. AFUDC represents the estimated cost of debt and equity funds that finance utility-plant construction and is capitalized during certain plant construction. AFUDC is recovered in rates through depreciation expense over the useful life of the related asset. AFUDC equity represents a method to compensate SCE for the estimated cost of equity used to finance utility plant additions and is recorded as part of construction in progress. AFUDC equity was $74 million , $87 million and $65 million in 2016 , 2015 and 2014 , respectively, and is reflected in "Interest and other income." AFUDC debt was $23 million , $31 million and $25 million in 2016 , 2015 and 2014 , respectively and is reflected as a reduction of "Interest expense." Major Maintenance Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred. Impairment of Long-Lived Assets Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair value is determined via market, cost and income based valuation techniques, as appropriate. SCE's impaired assets are recorded as a regulatory asset if it is deemed probable that such amounts will be recovered from customers. In 2014, the CPUC approved the San Onofre OII Settlement Agreement that SCE had entered into with a number of intervening parties. The San Onofre OII Settlement Agreement had resolved the CPUC's investigation regarding the Steam Generator Replacement Project at San Onofre and the related outages and subsequent shutdown of San Onofre. In 2014, SCE had recorded a pre-tax impairment charge of approximately $163 million (approximately $72 million after-tax). Including amounts previously recorded as an impairment charge in 2013, the total impact of the San Onofre OII Settlement Agreement was a pre-tax charge of $738 million (approximately $437 million after-tax). In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. See Note 11 for further information. Goodwill Edison International assesses goodwill through annual goodwill impairment tests, at the reporting unit level, as of October 1st of each year. The fair value of the Edison Energy and SoCore Energy reporting units exceeded their carrying values at the date of the annual impairment analysis. As of December 31, 2016, goodwill is comprised of $78 million at the Edison Energy reporting unit and $22 million at the SoCore Energy reporting unit. Edison International will update these tests between annual tests if events occur or circumstances change such that it is more likely than not that the fair value of a reporting unit is below its carrying value. Nuclear Decommissioning and Asset Retirement Obligations The fair value of a liability for an asset retirement obligation ("ARO") is recorded in the period in which it is incurred, including a liability for the fair value of a conditional ARO, if the fair value can be reasonably estimated even though uncertainty exists about the timing and/or method of settlement. When an ARO liability is initially recorded, SCE capitalizes the cost by increasing the carrying amount of the related long-lived asset. For each subsequent period, the liability is increased for accretion expense and the capitalized cost is depreciated over the useful life of the related asset. AROs related to decommissioning of SCE's nuclear power facilities are based on site-specific studies conducted as part of each Nuclear Decommissioning Cost Triennial Proceeding ("NDCTP") conducted before the CPUC. Revisions of an ARO are established for updated site-specific decommissioning cost estimates. SCE adjusts its nuclear decommissioning obligation into a nuclear-related ARO regulatory asset and also records an ARO regulatory liability as a result of timing differences between the recognition of costs and the recovery of costs through the ratemaking process. For further discussion, see Notes 9 and 10. SCE has not recorded an asset retirement obligation for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities. The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde: December 31, (in millions) 2016 2015 Beginning balance $ 2,762 $ 2,819 Accretion 1 157 173 Revisions (165 ) (14 ) Liabilities settled (168 ) (216 ) Ending balance $ 2,586 $ 2,762 1 An ARO represents the present value of a future obligation. Accretion is an increase in the liability to account for the time value of money resulting from discounting. The recorded liability to decommission SCE's nuclear power facilities (included in the table above) is $2.5 billion as of December 31, 2016. In 2016, SCE updated the recorded liability for Palo Verde and San Onofre Unit 1 based on the 2013 decommissioning study performed for Palo Verde and the 2014 study for San Onofre Unit 1. The recorded liability for San Onofre Unit 2 and 3 is based on a 2014 decommissioning study which followed the decision to permanently retire San Onofre. The 2015 NDTCP filing is expected to be updated for San Onofre Units 2 and 3 after onboarding the decommissioning general contractor and the subsequent development of a new decommissioning cost estimate during 2017. Decommissioning costs, which are recovered through customer rates over the term of each nuclear facility's operating license, are recorded as a component of depreciation expense, with a corresponding credit to the ARO regulatory liability. Amortization of the ARO asset (included within the unamortized nuclear investment) and accretion of the ARO liability are deferred as increases to the ARO regulatory liability account, resulting in no impact on earnings. SCE has collected in rates amounts for the future costs of removal of its nuclear assets, and has placed those amounts in independent trusts. The cost of removal amounts, in excess of amounts collected for assets not legally required to be removed, are classified as regulatory liabilities. Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $6.3 billion through 2079 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 1.7% to 7.5% (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 2.4% to 4.1% . Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts. If the assumed return on trust assets is not earned or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates. See Note 9 for further information. Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceeding. SCE's nuclear decommissioning trust investments primarily consist of fixed income and equity investments that are classified as available-for-sale. Due to regulatory mechanisms, earnings and realized gains and losses (including other-than-temporary impairments) have no impact on electric utility revenue. Unrealized gains and losses on decommissioning trust funds increase or decrease the trust assets and the related regulatory asset or liability and have no impact on electric utility revenue or decommissioning expense. SCE reviews each security for other-than-temporary impairment on the last day of each month. If the fair value on the last day of two consecutive months is less than the cost for that security, SCE recognizes a loss for the other-than-temporary impairment. If the fair value is greater or less than the cost for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively. Deferred Financing Costs Debt premium, discount and issuance expenses incurred in connection with obtaining financing are deferred and amortized on a straight-line basis. Under CPUC ratemaking procedures, SCE's debt reacquisition expenses are amortized over the remaining life of the reacquired debt or, if refinanced, the life of the new debt. SCE had unamortized losses on reacquired debt of $184 million and $201 million at December 31, 2016 and 2015 , respectively, reflected as long-term "Regulatory assets" in the consolidated balance sheets. Edison International and SCE had unamortized debt issuance costs of $10 million and $7 million at December 31, 2016 , respectively, and $11 million and $7 million at December 31, 2015 , respectively, reflected in "Other long-term assets" on the consolidated balance sheets. In addition, Edison International and SCE had debt issuance costs of $81 million and $71 million at December 31, 2016, respectively, and $81 million and $77 million at December 31, 2015, respectively, reflected as a reduction of "Long-term debt" on the consolidated balance sheets. Amortization of deferred financing costs charged to interest expense is as follows: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Amortization of deferred financing costs charged to interest expense $ 31 $ 33 $ 36 $ 27 $ 28 $ 32 Revenue Recognition Revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the end of each reporting period and reflected in "Operating revenue" on the consolidated statements of income. Rates charged to customers are based on CPUC- and FERC-authorized revenue requirements. CPUC rates are implemented subsequent to final approval. CPUC rates decouple authorized revenue from the volume of electricity sales. Differences between amounts collected and authorized levels are either collected from or refunded to customers, and therefore, SCE earns revenue equal to amounts authorized. FERC rates also decouple revenue from volume of electricity sales. In November 2013, the FERC approved a formula rate effective January 1, 2012 to determine SCE's FERC transmission revenue requirement, including its construction work in progress ("CWIP") revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. Differences between amounts collected and determined under the formula rate are either collected from or refunded to customers, and therefore, SCE earns revenue based on estimates of recorded rate base costs under the FERC formula rate. SCE bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which SCE pays to various municipalities (based on contracts with these municipalities) in order to operate within the limits of the municipality. SCE bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SCE's ability to collect from the customer, are accounted for on a gross basis and reflected in electric utility revenue and other operation and maintenance expense. SCE's franchise fees billed to customers and recorded as revenue were $111 million , $138 million and $134 million in 2016 , 2015 and 2014 , respectively. When SCE acts as an agent, the taxes are accounted for on a net basis. Amounts billed to and collected from customers for these taxes are remitted to the taxing authorities and are not recognized as electric utility revenue. Power Purchase Agreements SCE enters into power purchase agreements in the normal course of business. A power purchase agreement may be considered a variable interest in a variable interest entity. Under this classification, the power purchase agreement is evaluated to determine if SCE is the primary beneficiary in the variable interest entity, in which case, such entity would be consolidated. None of SCE's power purchase agreements resulted in consolidation of a variable interest entity at December 31, 2016 and 2015 . See Note 3 for further discussion of power purchase agreements that are considered variable interests. A power purchase agreement may also contain a lease for accounting purposes. This generally occurs when a power purchase agreement (signed or modified after June 30, 2003) designates a specific power plant in which the buyer purchases substantially all of the output and does not otherwise meet a fixed price per unit of output exception. SCE has a number of power purchase agreements that contain leases. SCE's recognition of lease expense conforms to the ratemaking treatment for SCE's recovery of the cost of electricity and is recorded in purchased power. See Note 11 for further discussion of SCE's power purchase agreements, including agreements that are classified as operating and capital leases for accounting purposes. A power purchase agreement that does not contain a lease may be classified as a derivative subject to a normal purchase and sale exception, in which case the power purchase agreement is classified as an executory contract and accounted for on an accrual basis. SCE purchases power under certain contracts that are not eligible for the normal purchase and sale exception and are recorded as a derivative on the consolidated balance sheets at fair value. Most of SCE's qualifying facilities ("QFs") contracts are not required to be recorded on the consolidated balance sheets because they either do not meet the definition of a derivative or meet the normal purchase and sale exception. See Note 6 for further information on derivative instruments. Power purchase agreements that do not meet the above classifications are accounted for on an accrual basis. Derivative Instruments SCE records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value unless otherwise exempted from derivative treatment as normal purchases or sales. The normal purchases and sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business. Realized gains and losses from SCE's derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, therefore, SCE's fair value changes have no impact on purchased-power expense or earnings. SCE does not use hedge accounting for derivative transactions due to regulatory accounting treatment. Where SCE's derivative instruments are subject to a master netting agreement and certain criteria are met, SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets. In addition, derivative positions are offset against margin and cash collateral deposits. The results of derivative activities are recorded as part of cash flows from operating activities on the consolidated statements of cash flows. See Note 6 for further information on derivative instruments. Leases SCE enters into power purchase agreements that may contain leases, as discussed under "Power Purchase Agreements" above. SCE has also entered into a number of agreements to lease property and equipment in the normal course of business. Minimum lease payments under operating leases are levelized (total minimum lease payments divided by the number of years of the lease) and recorded as rent expense over the terms of the leases. Lease payments in excess of the minimum are recorded as rent expense in the year incurred. Capital leases are reported as long-term obligations on the consolidated balance sheets in "Other deferred credits and other long-term liabilities." As a rate-regulated enterprise, SCE's capital lease amortization expense and interest expense are reflected in "Purchased power and fuel" on the consolidated statements of income. Stock-Based Compensation Stock options, performance shares, deferred stock units and restricted stock units have been granted under Edison International's long-term incentive compensation programs. Generally, Edison International does not issue new common stock for settlement of equity awards. Rather, a third party is used to purchase shares from the market and deliver such shares for the settlement of option exercises, performance shares, deferred stock units and restricted stock units. Performance shares awarded in 2014 that are earned are settled half in cash and half in common stock, while the performance shares awarded in 2016 and 2015 that are earned are settled solely in cash. Deferred stock units and restricted stock units are settled in common stock; however, Edison International will substitute cash awards to the extent necessary to pay tax withholding or any government levies. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. For awards granted to retirement-eligible participants stock compensation expenses are recognized on a prorated basis over the initial year or over the period between the date of grant and the date the participant first becomes eligible for retirement. Under new accounting guidance adopted in 2016, share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created. SCE Dividend Restrictions The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above 48% on a 13 -month weighted average basis. At December 31, 2016 , SCE's 13 -month weighted-average common equity component of total capitalization was 50.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $585 million , resulting in a restriction on net assets of approximately $13.9 billion . Earnings Per Share Edison International computes earnings per common share ("EPS") using the two-class method, which is an earnings allocation formula that determines EPS for each class of common stock and participating security. Edison International's participating securities are stock-based compensation awards payable in common shares, including performance shares and restricted stock units, which earn dividend equivalents on an equal basis with common shares once the awards are vested. EPS attributable to Edison International common shareholders was computed as follows: Years ended December 31, (in millions) 2016 2015 2014 Basic earnings per share – continuing operations: Income from continuing operations attributable to common shareholders $ 1,299 $ 985 $ 1,427 Participating securities dividends — (1 ) (1 ) Income from continuing operations available to common shareholders $ 1,299 $ 984 $ 1,426 Weighted average common shares outstanding 326 326 326 Basic earnings per share – continuing operations $ 3.99 $ 3.02 $ 4.38 Diluted earnings per share – continuing operations: Income from continuing operations attributable to common shareholders $ 1,299 $ 985 $ 1,427 Participating securities dividends — (1 ) (1 ) Income from continuing operations available to common shareholders $ 1,299 $ 984 $ 1,426 Income impact of assumed conversions 1 1 1 Income from continuing operations available to common shareholders and assumed conversions $ 1,300 $ 985 $ 1,427 Weighted average common shares outstanding 326 326 326 Incremental shares from assumed conversions 4 3 3 Adjusted weighted average shares – diluted 330 329 329 Diluted earnings per share – continuing operations $ 3.94 $ 2.99 $ 4.33 In addition to the participating securities discussed above, Edison International also may award stock options which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 167,795 , 2,046,045 and 125,345 shares of common stock for the years ended December 31, 2016 , 2015 and 2014 , respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive. Income Taxes Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets. Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Investment tax credits are deferred and amortized to income tax expense over the lives of the properties or the term of the power purchase agreement of the respective project. Interest income, interest expense and penalties associated with income taxes are reflected in "Income tax expense" on the consolidated statements of income. Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its subsidiaries. Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis. Redeemable Noncontrolling Interest Redeemable noncontrolling interest represents the portion of equity ownership in an entity that is not attributable to the equity holders of Edison International and which have rights to put their ownership back to a subsidiary of Edison International. Noncontrolling interest is initially recorded at fair value and is subsequently adjusted for income allocated to the noncontrolling interest and any distributions paid to the noncontrolling interest. Certain solar projects for commercial customers are organized as limited liability companies and have noncontrolling equity investors (referred to as tax equity investors) which are entitled to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary over time. These entities are consolidated for financial reporting purposes but is not subject to income taxes as the taxable income (loss) and investment tax credits are allocated to the respective owners. The total consolidated assets and liabilities of these entities were $74 million and $23 million , respectively, at December 31, 2016 and were $82 million and $32 million , respectively, at December 31, 2015. Income (loss) of these entities are allocated to the noncontrolling interest based on the hypothetical liquidation at book value ("HLBV") accounting method. The HLBV accounting method is an approach that calculates the change in the claims of each member on the net assets of the investment at the beginning and end of each period. Each member’s claim is equal to the amount each party would receive or pay if the net assets of the investment were to liquidate at book value. Under the contract provisions, the tax equity investors' claim on net assets decreases rapidly in early years due to allocation of tax benefits resulting in additional non-operating income allocated to Edison International ( $9 million and $16 million in 2016 and 2015, respectively). New Accounting Guidance Accounting Guidance Adopted In April 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct reduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At December 31, 2016, the amount of debt issuance costs that are reflected as a reduction of "Long-term debt" was $71 million for SCE and $81 million for Edison International. At December 31, 2015, the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a reduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International. In April 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guida

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment SCE's property, plant and equipment included in the consolidated balance sheets is composed of the following: December 31, (in millions) 2016 2015 Distribution $ 22,332 $ 20,871 Transmission 12,549 11,592 Generation 3,376 3,138 General plant and other 4,633 4,543 Accumulated depreciation (9,000 ) (8,548 ) 33,890 31,596 Construction work in progress 2,790 3,218 Nuclear fuel, at amortized cost 126 131 Total utility property, plant and equipment $ 36,806 $ 34,945 Capitalized Software Costs SCE capitalizes costs incurred during the application development stage of internal use software projects to property, plant, and equipment. SCE amortizes capitalized software costs ratably over the expected lives of the software, ranging from 5 to 15 years and commencing upon operational use. Capitalized software costs, included in general plant and other above, were $1.4 billion at both December 31, 2016 and 2015 and accumulated amortization was $0.8 billion and $0.9 billion , at December 31, 2016 and 2015 , respectively. Amortization expense for capitalized software was $249 million , $268 million and $271 million in 2016 , 2015 and 2014 , respectively. At December 31, 2016 , amortization expense is estimated to be approximately $243 million annually for 2017 through 2021 . Jointly Owned Utility Projects SCE owns undivided interests in several generating assets for which each participant provides its own financing. SCE's proportionate share of these assets is reflected in the consolidated balance sheets and included in the above table. SCE's proportionate share of expenses for each project is reflected in the consolidated statements of income. A portion of the investments in Palo Verde generating stations is included in regulatory assets on the consolidated balance sheets. For further information see Note 10. The following is SCE's investment in each asset as of December 31, 2016 : (in millions) Plant in Service Construction Work in Progress Accumulated Depreciation Nuclear Fuel (at amortized cost) Net Book Value Ownership Interest Transmission systems: Eldorado $ 235 $ 10 $ 21 $ — $ 224 59% Pacific Intertie 192 21 80 — 133 50% Generating station: Palo Verde (nuclear) 1,959 62 1,547 126 600 16% Total $ 2,386 $ 93 $ 1,648 $ 126 $ 957 In addition, SCE has ownership interests in jointly owned power poles with other companies.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 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 entities that own rooftop solar projects (for further information, see Note 1—Redeemable Noncontrolling Interests). Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs. Commercial and operating activities include construction, operation and maintenance, fuel procurement, dispatch and compliance with regulatory and contractual requirements. Variable Interest in VIEs that are not Consolidated Power Purchase Contracts SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with QFs that contain variable pricing provisions based on the price of natural gas. SCE has concluded that it is not the primary beneficiary of these VIEs since it does not control the commercial and operating activities of these entities. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is the operation and maintenance of the power plants. As of the balance sheet date, the carrying amount of assets and liabilities in SCE's consolidated balance sheet that relate to its involvement with VIEs result from amounts due under the PPAs or the fair value of those derivative contracts. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 11. As a result, there is no significant potential exposure to loss to SCE from its variable interest in these VIEs. The aggregate contracted capacity dedicated to SCE from these VIE projects was 4,353 MW and 4,062 MW at December 31, 2016 and 2015 , respectively, and the amounts that SCE paid to these projects were $788 million and $640 million for the years ended December 31, 2016 and 2015 , respectively. These amounts are recoverable in customer rates, subject to reasonableness review. Unconsolidated Trusts of SCE SCE Trust I, Trust II, Trust III, Trust IV and Trust V were formed in 2012, 2013, 2014, 2015 and 2016 respectively, for the exclusive purpose of issuing the 5.625% , 5.10% , 5.75% , 5.375% and 5.45% trust preference securities, respectively ("trust securities"). The trusts are VIEs. SCE has concluded that it is not the primary beneficiary of these VIEs as it does not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the trusts. SCE Trust I, Trust II, Trust III, Trust IV and Trust V issued to the public trust securities in the face amounts of $475 million , $400 million , $275 million , $325 million and $ 300 million (cumulative, liquidation amounts of $25 per share), respectively, and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series F, Series G, Series H, Series J and Series K Preference Stock issued by SCE in the principal amounts of $475 million , $400 million , $275 million , $325 million and $ 300 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities. The Series F, Series G, Series H, Series J and Series K Preference Stock and the corresponding trust securities do not have a maturity date. Upon any redemption of any shares of the Series F, Series G, Series H, Series J or Series K Preference Stock, a corresponding dollar amount of trust securities will be redeemed by the applicable trust (see Note 12 for further information). The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities if and when the SCE board of directors declares and makes dividend payments on the related Preference Stock. The applicable trust will use any dividends it receives on the related Preference Stock to make its corresponding distributions on the applicable series of trust securities. If SCE does not make a dividend payment to any of these trusts, SCE would be prohibited from paying dividends on its common stock. SCE has fully and unconditionally guaranteed the payment of the trust securities and trust distributions, if and when SCE pays dividends on the related Preference Stock. The Trust I, Trust II, Trust III and Trust IV balance sheets as of December 31, 2016 and 2015 consisted of investments of $475 million , $400 million , $275 million and $325 million in the Series F, Series G, Series H and Series J Preference Stock respectively, $475 million , $400 million , $275 million and $325 million of trust securities, respectively and $10,000 each of common stock. The Trust V balance sheet as of December 31, 2016 consisted of investments of $ 300 million in the Series K Preference Stock, $ 300 million of trust securities, and $10,000 of common stock. The following table provides a summary of the trusts' income statements: Years ended December 31, (in millions) Trust I Trust II Trust III Trust IV Trust V 2016 Dividend income $ 27 $ 20 $ 16 $ 17 $ 13 Dividend distributions 27 20 16 17 13 2015 Dividend income $ 27 $ 20 $ 16 $ 6 * Dividend distributions 27 20 16 6 * 2014 Dividend income $ 27 $ 20 $ 13 * * Dividend distributions 27 20 13 * * * Not applicable

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 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 December 31, 2016 and 2015 , nonperformance risk was not material for Edison International and SCE. Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value. Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds and money market funds. Level 2 – Edison International's and SCE's Level 2 assets and liabilities include fixed income securities, primarily consisting of U.S. government and agency bonds, municipal bonds and corporate bonds, and over-the-counter derivatives. The fair value of fixed income securities is determined using a market approach by obtaining quoted prices for similar assets and liabilities in active markets and inputs that are observable, either directly or indirectly, for substantially the full term of the instrument. The fair value of SCE's over-the-counter derivative contracts is determined using an income approach. SCE uses standard pricing models to determine the net present value of estimated future cash flows. Inputs to the pricing models include forward published or posted clearing prices from exchanges (New York Mercantile Exchange and Intercontinental Exchange) for similar instruments and discount rates. A primary price source that best represents trade activity for each market is used to develop observable forward market prices in determining the fair value of these positions. Broker quotes, prices from exchanges or comparison to executed trades are used to validate and corroborate the primary price source. These price quotations reflect mid-market prices (average of bid and ask) and are obtained from sources believed to provide the most liquid market for the commodity. Level 3 – The fair value of SCE's Level 3 assets and liabilities is determined using the income approach through various models and techniques that require significant unobservable inputs. This level includes tolling arrangements and derivative contracts that trade infrequently such as congestion revenue rights ("CRRs"). Edison International Parent and Other does not have any Level 3 assets and liabilities. Assumptions are made in order to value derivative contracts in which observable inputs are not available. Changes in fair value are based on changes to forward market prices, including extrapolation of short-term observable inputs into forecasted prices for illiquid forward periods. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of fair value of derivative instruments. SCE The following table sets forth assets and liabilities of SCE that were accounted for at fair value by level within the fair value hierarchy: December 31, 2016 (in millions) Level 1 Level 2 Level 3 Netting and Collateral 1 Total Assets at fair value Derivative contracts $ — $ 6 $ 68 $ — $ 74 Other 33 — — — 33 Nuclear decommissioning trusts: Stocks 2 1,547 — — — 1,547 Fixed Income 3 865 1,751 — — 2,616 Short-term investments, primarily cash equivalents 36 170 — — 206 Subtotal of nuclear decommissioning trusts 4 2,448 1,921 — — 4,369 Total assets 2,481 1,927 68 — 4,476 Liabilities at fair value Derivative contracts — — 1,157 — 1,157 Total liabilities — — 1,157 — 1,157 Net assets (liabilities) $ 2,481 $ 1,927 $ (1,089 ) $ — $ 3,319 December 31, 2015 (in millions) Level 1 Level 2 Level 3 Netting and Collateral 1 Total Assets at fair value Derivative contracts $ — $ — $ 163 $ — $ 163 Other 28 — — — 28 Nuclear decommissioning trusts: Stocks 2 1,460 — — — 1,460 Fixed Income 3 947 1,776 — — 2,723 Short-term investments, primarily cash equivalents 91 81 — — 172 Subtotal of nuclear decommissioning trusts 4 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 70% of SCE's equity investments were located in the United States at both December 31, 2016 and 2015 . 3 Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $79 million and $111 million at December 31, 2016 and 2015 , respectively. 4 Excludes net payables of $127 million and $24 million at December 31, 2016 and 2015 , which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases. Edison International Parent and Other Edison International Parent and Other assets measured at fair value consisted of money market funds of $23 million and $29 million at December 31, 2016 and 2015 , respectively, classified as Level 1. SCE Fair Value of Level 3 The following table sets forth a summary of changes in SCE's fair value of Level 3 net derivative assets and liabilities: December 31, (in millions) 2016 2015 Fair value of net liabilities at beginning of period $ (1,148 ) $ (902 ) Total realized/unrealized gains (losses): Included in regulatory assets and liabilities 1 59 (246 ) Fair value of net liabilities at end of period $ (1,089 ) $ (1,148 ) Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period $ (70 ) $ (311 ) 1 Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities. Edison International and SCE recognize the fair value for transfers in and transfers out of each level at the end of each reporting period. There were no significant transfers between any levels during 2016 and 2015 . Valuation Techniques Used to Determine Fair Value The process of determining fair value is the responsibility of SCE's risk management department, which reports to SCE's chief financial officer. This department obtains observable and unobservable inputs through broker quotes, exchanges and internal valuation techniques that use both standard and proprietary models to determine fair value. Each reporting period, the risk and finance departments collaborate to determine the appropriate fair value methodologies and classifications for each derivative. Inputs are validated for reasonableness by comparison against prior prices, other broker quotes and volatility fluctuation thresholds. Inputs used and valuations are reviewed period-over-period and compared with market conditions to determine reasonableness. The following table sets forth SCE's valuation techniques and significant unobservable inputs used to determine fair value for significant Level 3 assets and liabilities: Fair Value (in millions) Significant Range Assets Liabilities Valuation Technique(s) Unobservable Input (Weighted Average) Congestion revenue rights December 31, 2016 $ 67 $ — Market simulation model and auction prices Load forecast 3,708 MW - 22,840 MW Power prices 1 $3.65 - $99.58 Gas prices 2 $2.51 - $4.87 December 31, 2015 152 — Market simulation model and auction prices Load forecast 6,289 MW - 24,349 MW Power prices 1 $0 - $110.44 Gas prices 2 $1.98 - $5.72 Tolling December 31, 2016 — 1,154 Option model Volatility of gas prices 15% - 48% (20%) Volatility of power prices 29% - 71% (40%) Power prices $23.40 - $51.24 ($34.70) December 31, 2015 10 1,297 Option model Volatility of gas prices 15% - 58% (20%) Volatility of power prices 26% - 38% (30%) Power prices $24.15 - $46.93 ($34.80) 1 Prices are in dollars per megawatt-hour. 2 Prices are in dollars per million British thermal units. Level 3 Fair Value Sensitivity Congestion Revenue Rights For CRRs, where SCE is the buyer, generally increases (decreases) in forecasted load in isolation would result in increases (decreases) to the fair value. In general, an increase (decrease) in electricity and gas prices at illiquid locations tends to result in increases (decreases) to fair value; however, changes in electricity and gas prices in opposite directions may have varying results on fair value. Tolling Arrangements The fair values of SCE's tolling arrangements contain intrinsic value and time value. Intrinsic value is the difference between the market price and strike price of the underlying commodity. Time value is made up of several components, including volatility, time to expiration, and interest rates. The option model for tolling arrangements reflects plant specific information such as operating and start-up costs. For tolling arrangements where SCE is the buyer, increases in volatility of the underlying commodity prices would result in increases to fair value as it represents greater price movement risk. As power and gas prices increase, the fair value of tolling arrangements tends to increase. The valuation of tolling arrangements is also impacted by the correlation between gas and power prices. As the correlation increases, the fair value of tolling arrangements tends to decline. Nuclear Decommissioning Trusts SCE's nuclear decommissioning trust investments include equity securities, U.S. treasury securities and other fixed income securities. Equity and treasury securities are classified as Level 1 as fair value is determined by observable market prices in active or highly liquid and transparent markets. The remaining fixed income securities are classified as Level 2. The fair value of these financial instruments is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information. SCE's investment policies and CPUC requirements place limitations on the types and investment grade ratings of the securities that may be held by the nuclear decommissioning trust funds. These policies restrict the trust funds from holding alternative investments and limit the trust funds' exposures to investments in highly illiquid markets. With respect to equity and fixed income securities, the trustee obtains prices from third-party pricing services which SCE is able to independently corroborate as described below. The trustee monitors prices supplied by pricing services, including reviewing prices against defined parameters' tolerances and performs research and resolves variances beyond the set parameters. SCE corroborates the fair values of securities by comparison to other market-based price sources obtained by SCE's investment managers. Differences outside established thresholds are followed-up with the trustee and resolved. For each reporting period, SCE reviews the trustee determined fair value hierarchy and overrides the trustee level classification when appropriate. Fair Value of Debt Recorded at Carrying Value The carrying value and fair value of Edison International's and SCE's long-term debt (including current portion of long-term debt) are as follows: December 31, 2016 December 31, 2015 (in millions) Carrying Value 1 Fair Value Carrying Value 1 Fair Value Edison International $ 11,156 $ 12,368 $ 11,178 $ 12,252 SCE 10,333 11,539 10,539 11,592 1 Carrying value is net of debt issuance costs. The fair value of Edison International's and SCE's short-term and long-term debt is classified as Level 2 and is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes of new issue prices and relevant credit information. The carrying value of Edison International's and SCE's trade receivables and payables, other investments, and short-term debt approximates fair value.

Debt and Credit Agreements

Debt and Credit Agreements	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt and Credit Agreements	Debt and Credit Agreements Long-Term Debt The following table summarizes long-term debt (rates and terms are as of December 31, 2016 ) of Edison International and SCE: December 31, (in millions) 2016 2015 Edison International Parent and Other: Debentures and notes: 2017 – 2023 (2.95% to 3.75%) $ 800 $ 614 Other long-term debt 32 31 Current portion of long-term debt (402 ) (216 ) Unamortized debt discount and issuance costs, net (9 ) (6 ) Total Edison International Parent and Other 421 423 SCE: First and refunding mortgage bonds: 2017 – 2045 (1.125% to 6.05%) 9,357 9,436 Pollution-control bonds: 2028 – 2035 (1.375% to 5.0%) 1 774 909 Debentures and notes: 2029 – 2053 (5.06% to 6.65%) 307 307 Current portion of long-term debt (579 ) (79 ) Unamortized debt discount and issuance costs, net (105 ) (113 ) Total SCE 9,754 10,460 Total Edison International $ 10,175 $ 10,883 1 Excludes outstanding bonds that have not been retired and may be remarketed to investors in the future. These bonds have variable rates and are due in 2031 and 2033 at December 31, 2016 and 2031 at December 31, 2015. Edison International and SCE long-term debt maturities over the next five years are the following: (in millions) Edison International SCE 2017 $ 981 $ 579 2018 482 479 2019 82 79 2020 80 79 2021 580 579 Project Financings As of December 31, 2016 and 2015, indirect subsidiaries of Edison Energy Group owning solar projects had approximately $22 million and $25 million outstanding under a 7 -year term financing due in 2022 at a weighted average interest rate of 3.50% and 3.11% . In addition, tax equity investors in these solar projects receive 99% of taxable profits and losses and tax credits of the projects as determined for federal income tax purposes for a six -year period following the completion of the portfolio of projects and receive a priority return of 2% of their investment per year. After the six -year period, the tax equity investor receives 5% of the taxable profits and losses and cash flow. A subsidiary of Edison Energy Group has a call option for a nine -month period following five years after completion of the portfolio of projects to purchase the tax equity investors interest and the tax equity investor has the right to put its ownership interest to such subsidiary in the event that the call option is not exercised. An indirect subsidiary of Edison Energy Group also entered into a non-recourse debt financing to support equity contributions in certain solar projects through June 30, 2017. The maturity date of the borrowings under this agreement is December 31, 2036. As of December 31, 2016 and 2015, there was $10 million and $6 million outstanding under this agreement at a weighted average interest rate of 9% . Liens and Security Interests Almost all of SCE's properties are subject to a trust indenture lien. SCE has pledged first and refunding mortgage bonds as collateral for borrowed funds obtained from pollution-control bonds issued by government agencies. SCE has a debt covenant that requires a debt to total capitalization ratio be met. At December 31, 2016 , SCE was in compliance with this debt covenant. All of the properties subject to the Edison Energy Group project financings discussed above are subject to a lien. Credit Agreements and Short-Term Debt The following table summarizes the status of the credit facilities at December 31, 2016 : (in millions) Edison International Parent SCE Commitment $ 1,250 $ 2,750 Outstanding borrowings (538 ) (769 ) Outstanding letters of credit — (91 ) Amount available $ 712 $ 1,890 SCE and Edison International Parent have multi-year revolving credit facilities of $2.75 billion and $1.25 billion , respectively, with both maturing in July 2021. SCE's credit facility is generally used to support commercial paper borrowings and letters of credit issued for procurement-related collateral requirements, balancing account undercollections and for general corporate purposes, including working capital requirements to support operations and capital expenditures. Edison International Parent's credit facility is used to support commercial paper borrowings and for general corporate purposes. At December 31, 2016 , commercial paper supported by SCE's credit facility, net of discount, was $769 million at a weighted-average interest rate of 0.9% . At December 31, 2016 , letters of credit issued under SCE's credit facility aggregated $91 million and are scheduled to expire in twelve months or less. At December 31, 2015 , the outstanding commercial paper, net of discount, was $49 million at a weighted-average interest rate of 0.51% . At December 31, 2016 , Edison International Parent's outstanding commercial paper, net of discount, was $538 million at a weighted-average interest rate of 0.97% . This commercial paper was supported by the $1.25 billion multi-year revolving credit facility. At December 31, 2015 , the outstanding commercial paper, net of discount, was $646 million at a weighted-average interest rate of 0.78% . Debt Financing Subsequent to December 31, 2016 In January 2017, SCE borrowed $300 million under a Term Loan Agreement with a variable interest rate, initially set at 1.483% , due in July 2018. The proceeds were used for general corporate purposes. In January 2017, SCE reissued $135 million of 2.625% pollution-control bonds with a mandatory purchase date in December 2023. These bonds mature in November 2033. The proceeds were used for general corporate purposes.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 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 $12 million and $38 million as of December 31, 2016 and 2015 , respectively, for which SCE has posted $12 million collateral and no collateral to its counterparties at the respective dates for its derivative liabilities and related outstanding payables. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2016 , SCE would be required to post $4 million of additional collateral of which $4 million is related to outstanding payables that are net of collateral already posted. Fair Value of Derivative Instruments SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are offset against margin and cash collateral deposits. In addition, SCE has provided collateral in the form of letters of credit. Collateral requirements can vary depending upon the level of unsecured credit extended by counterparties, changes in market prices relative to contractual commitments and other factors. See Note 4 for a discussion of fair value of derivative instruments. The following table summarizes the gross and net fair values of SCE's commodity derivative instruments: December 31, 2016 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 74 $ 1 $ 75 $ 217 $ 941 $ 1,158 $ 1,083 Gross amounts offset in consolidated balance sheets (1 ) — (1 ) (1 ) — (1 ) — Cash collateral posted 1 — — — — — — — Net amounts presented in the consolidated balance sheets $ 73 $ 1 $ 74 $ 216 $ 941 $ 1,157 $ 1,083 December 31, 2015 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 81 $ 84 $ 165 $ 235 $ 1,100 $ 1,335 $ 1,170 Gross amounts offset in consolidated balance sheets (2 ) — (2 ) (2 ) — (2 ) — Cash collateral posted 1 — — — (15 ) — (15 ) (15 ) Net amounts presented in the consolidated balance sheets $ 79 $ 84 $ 163 $ 218 $ 1,100 $ 1,318 $ 1,155 1 In addition, at December 31, 2016 , SCE received $2 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015 , SCE had posted $31 million of cash collateral that is not offset against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets. Income Statement Impact of Derivative Instruments SCE recognizes realized gains and losses on derivative instruments as purchased power expense and expects that such gains or losses will be part of the purchase power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are recorded in cash flows from operating activities in the consolidated statements of cash flows. The following table summarizes the components of SCE's economic hedging activity: Years ended December 31, (in millions) 2016 2015 2014 Realized losses $ (59 ) $ (148 ) $ (57 ) Unrealized gains (losses) 84 (182 ) (147 ) Notional Volumes of Derivative Instruments The following table summarizes the notional volumes of derivatives used for SCE hedging activities: Economic Hedges Unit of December 31, Commodity Measure 2016 2015 Electricity options, swaps and forwards GWh 1,816 6,221 Natural gas options, swaps and forwards Bcf 36 32 Congestion revenue rights GWh 93,319 109,740 Tolling arrangements GWh 61,093 70,663

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Current and Deferred Taxes Edison International's sources of income (loss) before income taxes are: Years ended December 31, (in millions) 2016 2015 2014 Income from continuing operations before income taxes $ 1,590 $ 1,568 $ 1,979 Income (loss) from discontinued operations before income taxes 1 15 (525 ) Income before income tax $ 1,591 $ 1,583 $ 1,454 The components of income tax expense (benefit) by location of taxing jurisdiction are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Current: Federal $ (46 ) $ 18 $ (99 ) $ 75 $ 72 $ (89 ) State 33 19 20 93 127 101 (13 ) 37 (79 ) 168 199 12 Deferred: Federal 176 340 454 112 298 476 State 14 109 68 (24 ) 10 (14 ) 190 449 522 88 308 462 Total continuing operations 177 486 443 256 507 474 Discontinued operations 1 (11 ) (21 ) (710 ) — — — Total $ 166 $ 465 $ (267 ) $ 256 $ 507 $ 474 1 See Note 15 for a discussion of discontinued operations related to EME. The components of net accumulated deferred income tax liability are: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Deferred tax assets: Property and software related $ 549 $ 675 $ 548 $ 675 Nuclear decommissioning trust assets in excess of nuclear ARO liability 348 360 348 360 Loss and credit carryforwards 1,418 1,388 — — Regulatory balancing accounts 15 21 15 21 Pension and PBOPs 300 337 93 154 Other 419 499 408 411 Sub-total 3,049 3,280 1,412 1,621 Less valuation allowance 24 32 — — Total 3,025 3,248 1,412 1,621 Deferred tax liabilities: Property-related 10,330 9,606 10,330 9,600 Capitalized software costs 237 207 237 207 Regulatory balancing accounts 134 202 134 202 Nuclear decommissioning trust assets 348 360 348 360 PBOPs 13 71 13 71 Other 202 189 148 161 Total 11,264 10,635 11,210 10,601 Accumulated deferred income tax liability, net 1 $ 8,239 $ 7,387 $ 9,798 $ 8,980 1 Included in deferred income taxes and credits. Net Operating Loss and Tax Credit Carryforwards The amounts of net operating loss and tax credit carryforwards (after-tax) are as follows: Edison International SCE December 31, 2016 (in millions) Loss Carryforwards Credit Carryforwards Loss Carryforwards Credit Carryforwards Expire between 2017 to 2035 $ 1,095 $ 430 $ 20 $ 25 No expiration date — 69 — 37 Total 1 $ 1,095 $ 499 $ 20 $ 62 1 Deferred tax assets for net operating loss and tax credit carryforwards are reduced by unrecognized tax benefits of $176 million and $82 million for Edison International and SCE, respectively. Edison International has recorded a valuation allowance of $24 million for state net operating loss carryforwards estimated to expire unused. In 2016, Edison International determined that $8 million of the assets subject to a valuation allowance, had no expectation of recovery and were written off. At December 31, 2015, Edison International and SCE had $42 million and $6 million , respectively, of federal net operating loss carryforwards related to the tax benefit on employee stock plans that would be recorded to additional paid-in capital when realized. In March 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. As part of this new guidance adopted in 2016, Edison International and SCE recorded an increase to beginning retained earnings for these amounts. Refer to Note 1 for further information. Edison International consolidates for federal income tax purposes, but not for financial accounting purposes, a group of wind projects referred to as Capistrano Wind. The amount of net operating loss and tax credit carryforwards recognized as part of deferred income taxes includes $242 million and $210 million related to Capistrano Wind at December 31, 2016 and 2015, respectively. Under a tax allocation agreement, Edison International has recorded the liability as part of other long-term liabilities related to its obligation to make payments to Capistrano Wind of these tax benefits when realized. Effective Tax Rate The table below provides a reconciliation of income tax expense computed at the federal statutory income tax rate to the income tax provision: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Income from continuing operations before income taxes $ 1,590 $ 1,568 $ 1,979 $ 1,755 $ 1,618 $ 2,039 Provision for income tax at federal statutory rate of 35% 556 549 693 614 566 714 Increase in income tax from: Items presented with related state income tax, net: Regulatory asset write-off 1 — 382 — — 382 — State tax, net of federal benefit 29 5 56 43 34 55 Property-related 2 (362 ) (341 ) (252 ) (362 ) (341 ) (252 ) Change related to uncertain tax positions (4 ) (67 ) 5 (8 ) (94 ) 12 San Onofre OII settlement — — (23 ) — — (23 ) Share-based compensation 3 (28 ) — — (13 ) — — Other (14 ) (42 ) (36 ) (18 ) (40 ) (32 ) Total income tax expense from continuing operations $ 177 $ 486 $ 443 $ 256 $ 507 $ 474 Effective tax rate 11.1 % 31.0 % 22.4 % 14.6 % 31.3 % 23.2 % 1 Includes federal and state. 2 Includes incremental repair benefits. See discussion of repair deductions below. 3 Includes state taxes of $(4) million and $(1) million for Edison International and SCE, respectively. Refer to Note 1 for further information. The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates. Repair Deductions Edison International made voluntary elections in 2009 and 2011 to change its tax accounting method for certain tax repair costs incurred on SCE's transmission, distribution and generation assets. Incremental repair deductions represent amounts recognized for regulatory accounting purposes in excess of amounts included in the authorized revenue requirements through the GRC proceedings. Incremental repair deductions for the years 2012 – 2014 resulted in additional income tax benefits of $133 million in 2014. As part of the final decision in SCE's 2015 GRC, the CPUC adopted a rate base offset associated with these incremental tax repair deductions during 2012 – 2014. The 2015 rate base offset is $324 million and amortizes on a straight line basis over 27 years. As a result of the rate base offset included in the final decision, SCE recorded an after tax charge of $382 million in 2015 to write down the net regulatory asset for recovery of deferred income taxes related to 2012 – 2014 incremental tax repair deductions which is reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductions the CPUC used to establish the rate base offset was based on SCE's forecast of 2012 – 2014 tax repair deductions from the Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In April 2016, the CPUC granted SCE's request to reduce SCE's BRRBA by $234 million in future periods subject to the timing and final outcome of audits that may be conducted by tax authorities. The refunds will result in flowing incremental tax benefits for 2012 – 2014 to customers. SCE refunded $133 million ( $79 million after-tax) during the second quarter of 2016. SCE did not record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings. Accounting for Uncertainty in Income Taxes Authoritative guidance related to accounting for uncertainty in income taxes requires an enterprise to recognize, in its financial statements, the best estimate of the impact of a tax position by determining if the weight of the available evidence indicates it is more likely than not, based solely on the technical merits, that the position will be sustained upon examination. The guidance requires the disclosure of all unrecognized tax benefits, which includes both the reserves recorded for tax positions on filed tax returns and the unrecognized portion of affirmative claims. Unrecognized Tax Benefits The following table provides a reconciliation of unrecognized tax benefits for continuing and discontinued operations: Edison International SCE December 31, (in millions) 2016 2015 2014 2016 2015 2014 Balance at January 1, $ 529 $ 576 $ 815 $ 353 $ 441 $ 532 Tax positions taken during the current year: Increases 36 54 65 36 48 57 Tax positions taken during a prior year: Increases 2 66 1 — 23 — Decreases 1 (96 ) (165 ) (143 ) (18 ) (159 ) (93 ) Decreases for settlements during the period 2 — (2 ) (162 ) — — (55 ) Balance at December 31, $ 471 $ 529 $ 576 $ 371 $ 353 $ 441 1 Decreases in prior year tax positions for 2016 relate to state tax receivables on various claims. Due to the tax risks associated with these claims, the tax benefits were fully reserved at the time the asset was recorded. During 2016, the Company has determined that it will not recognize these assets so the tax benefit and related tax reserve were written off. Decreases in tax positions for 2015 relate primarily to re-measurement of uncertain tax positions in connection with receipt of the IRS Revenue Agent Report in June 2015. See discussions in Tax Disputes below. 2 In the fourth quarter of 2014, Edison International has settled all open tax positions with the IRS for taxable years 2003 through 2006. As of December 31, 2016 and 2015 , if recognized, $347 million and $440 million , respectively, of the unrecognized tax benefits would impact Edison International's effective tax rate; and $243 million and $256 million , respectively, of the unrecognized tax benefits would impact SCE's effective tax rate. Tax Disputes Tax Years 2007 – 2012 Edison International has reached a tentative settlement agreement with the IRS for the 2007 – 2012 tax years. The final agreement, when approved, is not expected to have a material impact on the financial statements. During 2015, the Company received the IRS Revenue Agent Report for the 2010 – 2012 tax years. Edison International's and SCE's tax reserves were re-measured at that time and $94 million and $100 million , respectively, of income tax benefits were recorded in the comparable quarter for the prior year. Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 2007 – 2015 and 2003 – 2015, respectively. Accrued Interest and Penalties The total amount of accrued interest and penalties related to income tax liabilities for continuing and discontinued operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Accrued interest and penalties $ 128 $ 122 $ 41 $ 40 The net after-tax interest and penalties recognized in income tax expense for continuing and discontinued operations are: Edison International SCE December 31, (in millions) 2016 2015 2014 2016 2015 2014 Net after-tax interest and penalties tax benefit $ 6 $ 9 $ 41 $ 2 $ 14 $ 16

Compensation and Benefit Plans

Compensation and Benefit Plans	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Compensation and Benefit Plans	Compensation and Benefit Plans Employee Savings Plan The 401(k) defined contribution savings plan is designed to supplement employees' retirement income. The following employer contributions were made for continuing operations: Edison International SCE (in millions) Years ended December 31, 2016 $ 69 $ 68 2015 73 72 2014 71 70 Pension Plans and Postretirement Benefits Other Than Pensions Pension Plans Noncontributory defined benefit pension plans (some with cash balance features) cover most employees meeting minimum service requirements. SCE recognizes pension expense for its nonexecutive plan as calculated by the actuarial method used for ratemaking. The expected contributions (all by the employer) for Edison International and SCE are approximately $136 million and $85 million , respectively, for the year ending December 31, 2017 . Annual contributions made by SCE to most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms. The funded position of Edison International's pension is sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's pension are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, a regulatory asset has been recorded equal to the unfunded status (See Note 10). Information on pension plan assets and benefit obligations for continuing and discontinued operations is shown below. Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Change in projected benefit obligation Projected benefit obligation at beginning of year $ 4,374 $ 4,517 $ 3,878 $ 3,999 Service cost 139 142 132 133 Interest cost 171 170 150 150 Actuarial gain (125 ) (149 ) (140 ) (143 ) Benefits paid (275 ) (305 ) (229 ) (261 ) Other — (1 ) — — Projected benefit obligation at end of year $ 4,284 $ 4,374 $ 3,791 $ 3,878 Change in plan assets Fair value of plan assets at beginning of year $ 3,298 $ 3,454 $ 3,080 $ 3,217 Actual return on plan assets 262 30 239 27 Employer contributions 103 119 82 97 Benefits paid (275 ) (305 ) (229 ) (261 ) Fair value of plan assets at end of year $ 3,388 $ 3,298 $ 3,172 $ 3,080 Funded status at end of year $ (896 ) $ (1,076 ) $ (619 ) $ (798 ) Amounts recognized in the consolidated balance sheets consist of 1 : Long-term assets $ 2 $ — $ — $ — Current liabilities (50 ) (27 ) (4 ) (4 ) Long-term liabilities (848 ) (1,049 ) (615 ) (794 ) $ (896 ) $ (1,076 ) $ (619 ) $ (798 ) Amounts recognized in accumulated other comprehensive loss consist of: Prior service cost $ (1 ) $ — $ — $ — Net loss 1 93 96 24 27 $ 92 $ 96 $ 24 $ 27 Amounts recognized as a regulatory asset $ 574 $ 675 $ 574 $ 675 Total not yet recognized as expense $ 666 $ 771 $ 598 $ 702 Accumulated benefit obligation at end of year $ 4,138 $ 4,200 $ 3,683 $ 3,744 Pension plans with an accumulated benefit obligation in excess of plan assets: Projected benefit obligation $ 4,284 $ 4,374 $ 3,791 $ 3,878 Accumulated benefit obligation 4,138 4,200 3,683 3,744 Fair value of plan assets 3,388 3,298 3,172 3,080 Weighted-average assumptions used to determine obligations at end of year: Discount rate 3.94 % 4.18 % 3.94 % 4.18 % Rate of compensation increase 4.00 % 4.00 % 4.00 % 4.00 % 1 The SCE liability excludes a long-term payable due to Edison International Parent of $124 million and $123 million at December 31, 2016 and 2015 , respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent. SCE's accumulated other comprehensive loss of $24 million and $27 million at December 31, 2016 and 2015 , respectively, excludes net loss of $ 20 million and $18 million related to these benefits. Pension expense components for continuing operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Service cost $ 139 $ 142 $ 133 $ 136 $ 139 $ 128 Interest cost 172 170 181 156 155 164 Expected return on plan assets (220 ) (233 ) (229 ) (205 ) (217 ) (213 ) Settlement costs 1 — — 45 — — 42 Curtailment gain — — (4 ) — — — Amortization of prior service cost 4 5 5 4 5 5 Amortization of net loss 2 27 40 12 23 35 7 Expense under accounting standards 122 124 143 114 117 133 Regulatory adjustment (deferred) (21 ) (6 ) 8 (21 ) (6 ) 8 Total expense recognized $ 101 $ 118 $ 151 $ 93 $ 111 $ 141 1 Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International was zero for the both the years ended December 31, 2016 and 2015 and $3 million for the year ended December 31, 2014 . 2 Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $10 million and $6 million , respectively, for the year ended December 31, 2016 . The amount reclassified for Edison International and SCE was $14 million and $8 million , respectively, for the year ended December 31, 2015 . The amount reclassified for Edison International and SCE was $9 million and $4 million , respectively, for the year ended December 31, 2014 . Under GAAP, a settlement is recorded when lump-sum payments exceed estimated annual service and interest costs. Lump-sum payments to employees retiring in 2014 from the SCE Retirement Plan (primarily due to workforce reductions described below) exceeded the estimated service and interest costs for that year. A settlement requires re-measurement of both the plan pension obligations and plan assets as of the date of the settlement. Re-measurement assumption changes result in actuarial gains and losses which are combined with previous unrecognized gains and losses. After re-measurement, GAAP requires an acceleration of a portion of unrecognized net losses attributable to such lump-sum payments as additional pension expense as reflected in the above table. The additional pension expense related to SCE did not impact net income as such amounts are probable of recovery through future rates. Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing operations: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Net loss (gain) $ 6 $ 7 $ 85 $ 4 $ (9 ) $ 37 Amortization of net loss and other (10 ) (15 ) (13 ) (6 ) (9 ) (4 ) Total recognized in other comprehensive loss $ (4 ) $ (8 ) $ 72 $ (2 ) $ (18 ) $ 33 Total recognized in expense and other comprehensive loss $ 97 $ 110 $ 223 $ 91 $ 93 $ 174 In accordance with authoritative guidance on rate-regulated enterprises, SCE records regulatory assets and liabilities instead of charges and credits to other comprehensive income (loss) for the portion of SCE's postretirement benefit plans that are recoverable in utility rates. The estimated pension amounts that will be amortized to expense in 2017 for continuing operations are as follows: (in millions) Edison International SCE Unrecognized net loss to be amortized 1 $ 19 $ 15 Unrecognized prior service cost to be amortized 3 3 1 The amount of net loss expected to be reclassified from other comprehensive loss for Edison International's continuing operations and SCE is $10 million and $6 million , respectively. Edison International and SCE used the following weighted-average assumptions to determine pension expense for continuing operations: Years ended December 31, 2016 2015 2014 Discount rate 4.18 % 3.85 % 4.50 % Rate of compensation increase 4.00 % 4.00 % 4.00 % Expected long-term return on plan assets 7.00 % 7.00 % 7.00 % The following benefit payments, which reflect expected future service, are expected to be paid: Edison International SCE (in millions) Years ended December 31, 2017 $ 346 $ 271 2018 332 298 2019 344 300 2020 341 304 2021 341 304 2022 – 2026 1,566 1,396 Postretirement Benefits Other Than Pensions ("PBOP(s)") Most employees retiring at or after age 55 with at least 10 years of service may be eligible for postretirement medical, dental, vision and life insurance benefits. Eligibility for a company contribution toward the cost of these benefits in retirement depends on a number of factors, including the employee's years of service, age, hire date, and retirement date. Under the terms of the Edison International Welfare Benefit Plan ("PBOP Plan") each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of all PBOP benefits with respect to its employees and former employees. A participating employer may terminate the PBOP benefits with respect to its employees and former employees, as may SCE (as Plan sponsor), and, accordingly, the participants' PBOP benefits are not vested benefits. The expected contributions (substantially all of which are expected to be made by SCE) for PBOP benefits are $21 million for the year ended December 31, 2017 . Annual contributions related to SCE employees made to SCE plans are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the total annual expense for these plans. SCE has established three voluntary employee beneficiary associations trusts ("VEBA Trusts") that can only be used to pay for retiree health care benefits of SCE. Once funded into the VEBA Trusts, neither SCE nor Edison International can subsequently terminate benefits and recover remaining amounts in the VEBA Trusts. Participants of the PBOP Plan do not have a beneficial interest in the VEBA Trusts. The VEBA Trust assets are sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's other postretirement benefits are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, the unfunded status is offset by a regulatory asset. Information on PBOP Plan assets and benefit obligations is shown below: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Change in benefit obligation Benefit obligation at beginning of year $ 2,350 $ 2,784 $ 2,341 $ 2,775 Service cost 35 46 34 46 Interest cost 97 102 97 102 Special termination benefits 2 (2 ) 2 (2 ) Plan Amendments (6 ) — (6 ) — Actuarial gain (110 ) (500 ) (110 ) (500 ) Plan participants' contributions 19 20 19 20 Benefits paid (111 ) (100 ) (111 ) (100 ) Benefit obligation at end of year $ 2,276 $ 2,350 $ 2,266 $ 2,341 Change in plan assets Fair value of plan assets at beginning of year $ 2,036 $ 2,086 $ 2,036 $ 2,086 Actual return on assets 137 6 137 6 Employer contributions 21 24 21 24 Plan participants' contributions 19 20 19 20 Benefits paid (111 ) (100 ) (111 ) (100 ) Fair value of plan assets at end of year $ 2,102 $ 2,036 $ 2,102 $ 2,036 Funded status at end of year $ (174 ) $ (314 ) $ (164 ) $ (305 ) Amounts recognized in the consolidated balance sheets consist of: Current liabilities $ (14 ) $ (15 ) $ (13 ) $ (15 ) Long-term liabilities (160 ) (299 ) (151 ) (290 ) $ (174 ) $ (314 ) $ (164 ) $ (305 ) Amounts recognized in accumulated other comprehensive loss consist of: Net loss $ 4 $ 4 $ — $ — Amounts recognized as a regulatory asset $ 136 $ 174 $ 136 $ 174 Total not yet recognized as expense $ 140 $ 178 $ 136 $ 174 Weighted-average assumptions used to determine obligations at end of year: Discount rate 4.29 % 4.55 % 4.29 % 4.55 % Assumed health care cost trend rates: Rate assumed for following year 7.00 % 7.50 % 7.00 % 7.50 % Ultimate rate 5.00 % 5.00 % 5.00 % 5.00 % Year ultimate rate reached 2022 2022 2022 2022 During 2016 and 2015, the PBOP plan had actuarial gains of $110 million and $500 million , respectively. The 2016 actuarial gain is primarily related to $165 million in experience gain, offsetting by $95 million loss from a decrease in the discount rate (from 4.55% as of December 31, 2015 to 4.29% as of December 31, 2016), and the adoption of new mortality tables, as discussed below. The 2015 actuarial gain is primarily related to $300 million in experience gains, $140 million of income from an increase in the discount rate (from 4.16% at December 31, 2014 to 4.55% as of December 31, 2015) due to higher interest rates, and the adoption of new mortality tables, as discussed below. In 2016 and 2015, Edison International and SCE adopted new mortality tables that the Society of Actuaries released in October each year that reflect changes in life expectancy. At December 31, 2016 and 2015, this adoption resulted in a change in Edison International's PBOP plans' accumulated postretirement benefit obligation of $(40) million and $(62) million , respectively, including $(40) million and $(61) million , respectively, for SCE. PBOP expense components for continuing operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Service cost $ 35 $ 46 $ 40 $ 34 $ 46 $ 40 Interest cost 97 102 117 97 102 117 Expected return on plan assets (112 ) (116 ) (108 ) (112 ) (116 ) (108 ) Special termination benefits 1 2 1 3 2 1 3 Amortization of prior service credit (2 ) (12 ) (36 ) (2 ) (12 ) (35 ) Amortization of net loss — 3 6 — 2 5 Total expense $ 20 $ 24 $ 22 $ 19 $ 23 $ 22 1 Due to the reduction in workforce, SCE has incurred costs for extended retiree health care coverage. In accordance with authoritative guidance on rate-regulated enterprises, SCE records regulatory assets and liabilities instead of charges and credits to other comprehensive income (loss) for the portion of SCE's postretirement benefit plans that are recoverable in utility rates. The estimated PBOP amounts that will be amortized to expense in 2017 for continuing operations are as follows: Edison International SCE Unrecognized prior service credit to be amortized $ (2 ) $ (2 ) Edison International and SCE used the following weighted-average assumptions to determine PBOP expense for continuing operations: Years ended December 31, 2016 2015 2014 Discount rate 4.55 % 4.16 % 5.00 % Expected long-term return on plan assets 5.60 % 5.50 % 5.50 % Assumed health care cost trend rates: Current year 7.50 % 7.75 % 7.75 % Ultimate rate 5.00 % 5.00 % 5.00 % Year ultimate rate reached 2022 2021 2020 A one-percentage-point change in assumed health care cost trend rate would have the following effects on continuing operations: Edison International SCE (in millions) One-Percentage-Point Increase One-Percentage-Point Decrease One-Percentage-Point Increase One-Percentage-Point Decrease Effect on accumulated benefit obligation as of December 31, 2016 $ 244 $ (200 ) $ 243 $ (199 ) Effect on annual aggregate service and interest costs 11 (9 ) 11 (9 ) The following benefit payments are expected to be paid: Edison International SCE (in millions) Years ended December 31, 2017 $ 98 $ 98 2018 102 102 2019 105 105 2020 109 109 2021 113 112 2022 – 2026 612 609 Plan Assets Description of Pension and Postretirement Benefits Other than Pensions Investment Strategies The investment of plan assets is overseen by a fiduciary investment committee. Plan assets are invested using a combination of asset classes, and may have active and passive investment strategies within asset classes. Target allocations for 2016 pension plan assets were 29% for U.S. equities, 17% for non-U.S. equities, 35% for fixed income, 15% for opportunistic and/or alternative investments and 4% for other investments. Target allocations for 2016 PBOP plan assets (except for Represented VEBA which is 85% for fixed income, 10% for opportunistic/private equities, and 5% global equities) are 41% for U.S. equities, 17% for non-U.S. equities, 34% for fixed income, 7% for opportunistic and/or alternative investments, and 1% for other investments. Edison International employs multiple investment management firms. Investment managers within each asset class cover a range of investment styles and approaches. Risk is managed through diversification among multiple asset classes, managers, styles and securities. Plan asset classes and individual manager performances are measured against targets. Edison International also monitors the stability of its investment managers' organizations. Allowable investment types include: • United States Equities: Common and preferred stocks of large, medium, and small companies which are predominantly United States-based. • Non-United States Equities: Equity securities issued by companies domiciled outside the United States and in depository receipts which represent ownership of securities of non-United States companies. • Fixed Income: Fixed income securities issued or guaranteed by the United States government, non-United States governments, government agencies and instrumentalities including municipal bonds, mortgage backed securities and corporate debt obligations. A portion of the fixed income positions may be held in debt securities that are below investment grade. Opportunistic, Alternative and Other Investments: • Opportunistic: Investments in short to intermediate term market opportunities. Investments may have fixed income and/or equity characteristics and may be either liquid or illiquid. • Alternative: Limited partnerships that invest in non-publicly traded entities. • Other: Investments diversified among multiple asset classes such as global equity, fixed income currency and commodities markets. Investments are made in liquid instruments within and across markets. The investment returns are expected to approximate the plans' expected investment returns. Asset class portfolio weights are permitted to range within plus or minus 3% . Where approved by the fiduciary investment committee, futures contracts are used for portfolio rebalancing and to reallocate portfolio cash positions. Where authorized, a few of the plans' investment managers employ limited use of derivatives, including futures contracts, options, options on futures and interest rate swaps in place of direct investment in securities to gain efficient exposure to markets. Derivatives are not used to leverage the plans or any portfolios. Determination of the Expected Long-Term Rate of Return on Assets The overall expected long-term rate of return on assets assumption is based on the long-term target asset allocation for plan assets and capital markets return forecasts for asset classes employed. A portion of the PBOP trust asset returns are subject to taxation, so the expected long-term rate of return for these assets is determined on an after-tax basis. Capital Markets Return Forecasts SCE's capital markets return forecast methodologies primarily use a combination of historical market data, current market conditions, proprietary forecasting expertise, complex models to develop asset class return forecasts and a building block approach. The forecasts are developed using variables such as real risk-free interest, inflation, and asset class specific risk premiums. For equities, the risk premium is based on an assumed average equity risk premium of 5% over cash. The forecasted return on private equity and opportunistic investments are estimated at a 2% premium above public equity, reflecting a premium for higher volatility and lower liquidity. For fixed income, the risk premium is based off of a comprehensive modeling of credit spreads. Fair Value of Plan Assets The PBOP Plan and the Southern California Edison Company Retirement Plan Trust (Master Trust) assets include investments in equity securities, U.S. treasury securities, other fixed-income securities, common/collective funds, mutual funds, other investment entities, foreign exchange and interest rate contracts, and partnership/joint ventures. Equity securities, U.S. treasury securities, mutual and money market funds are classified as Level 1 as fair value is determined by observable, unadjusted quoted market prices in active or highly liquid and transparent markets. The fair value of the underlying investments in equity mutual funds are based on stock-exchange prices. The fair value of the underlying investments in fixed-income mutual funds and other fixed income securities including municipal bonds are based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information. Foreign exchange and interest rate contracts are classified as Level 2 because the values are based on observable prices but are not traded on an exchange. Futures contracts trade on an exchange and therefore are classified as Level 1. Common/collective funds and partnerships are measured at fair value using the net asset value per share ("NAV") and have not been classified in the fair value hierarchy. Other investment entities are valued similarly to common/collective funds and are therefore classified as NAV. The Level 1 registered investment companies are either mutual or money market funds. The remaining funds in this category are readily redeemable and classified as NAV and are discussed further at Note 8 to the pension plan master trust investments table below. Edison International reviews the process/procedures of both the pricing services and the trustee to gain an understanding of the inputs/assumptions and valuation techniques used to price each asset type/class. The trustee and Edison International's validation procedures for pension and PBOP equity and fixed income securities are the same as the nuclear decommissioning trusts. For further discussion see Note 4. The values of Level 1 mutual and money market funds are publicly quoted. The trustees obtain the values of common/collective and other investment funds from the fund managers. The values of partnerships are based on partnership valuation statements updated for cash flows. SCE's investment managers corroborate the trustee fair values. Pension Plan The following table sets forth the Master Trust investments for Edison International and SCE that were accounted for at fair value as of December 31, 2016 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 217 $ 309 $ — $ — $ 526 Corporate stocks 3 720 15 — — 735 Corporate bonds 4 — 725 — — 725 Common/collective funds 5 — — — 692 692 Partnerships/joint ventures 6 — — — 333 333 Other investment entities 7 — — — 253 253 Registered investment companies 8 124 — — 6 130 Interest-bearing cash 42 — — — 42 Other — 112 — — 112 Total $ 1,103 $ 1,161 $ — $ 1,284 $ 3,548 Receivables and payables, net (160 ) Net plan assets available for benefits $ 3,388 SCE's share of net plan assets $ 3,172 The following table sets forth the Master Trust investments that were accounted for at fair value as of December 31, 2015 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 127 $ 298 $ — $ — $ 425 Corporate stocks 3 720 16 — — 736 Corporate bonds 4 — 755 — — 755 Common/collective funds 5 — — — 640 640 Partnerships/joint ventures 6 — — — 325 325 Other investment entities 7 — — — 263 263 Registered investment companies 8 117 — — 4 121 Interest-bearing cash 6 — — — 6 Other 1 96 — — 97 Total $ 971 $ 1,165 $ — $ 1,232 $ 3,368 Receivables and payables, net (70 ) Net plan assets available for benefits $ 3,298 SCE's share of net plan assets $ 3,080 1 These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits. 2 Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal National Mortgage Association and the Federal Home Loan Mortgage Corporation. 3 Corporate stocks are diversified. At December 31, 2016 and 2015 , respectively, performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 62% ) and ( 59% ) and Morgan Stanley Capital International (MSCI) index ( 38% ) and ( 41% ). 4 Corporate bonds are diversified. At December 31, 2016 and 2015 , respectively, this category includes $76 million and $123 million for collateralized mortgage obligations and other asset backed securities of which $27 million and $25 million are below investment grade. 5 At December 31, 2016 and 2015 , respectively, the common/collective assets were invested in equity index funds that seek to track performance of the Standard and Poor's (S&P 500) Index ( 45% and 46% ) and Russell 1000 indexes ( 15% and 14% ). At December 31, 2016 and 2015, 15% and 16% of the assets in this category are in index funds which seek to track performance in the MSCI All Country World Index exUS and MSCI Europe, Australasia and Far East (EAFE) Index, respectively. A non-index U.S. equity fund representing 23% and 22% of this category for 2016 and 2015 , respectively, is actively managed. 6 At December 31, 2016 and 2015 , respectively, 55% and 51% are invested in private equity funds with investment strategies that include branded consumer products, clean technology and California geographic focus companies, 22% and 20% are invested in publicly traded fixed income securities, 18% and 14% are invested in a broad range of financial assets in all global markets and 4% and 15% of the remaining partnerships are invested in asset backed securities, including distressed mortgages and commercial and residential loans and debt and equity of banks. 7 Other investment entities were primarily invested in (1) emerging market equity securities, (2) a hedge fund that invests through liquid instruments in a global diversified portfolio of equity, fixed income, interest rate, foreign currency and commodities markets, and (3) domestic mortgage backed securities. 8 Level 1 of registered investment companies primarily consisted of a global equity mutual fund which seeks to outperform the MSCI World Total Return Index. The funds classified as NAV primarily consisted of a fixed income securities fund. At December 31, 2016 and 2015 , respectively, approximately 69% and 63% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States. Postretirement Benefits Other than Pensions The following table sets forth the VEBA Trust assets for Edison International and SCE that were accounted for at fair value as of December 31, 2016 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 222 $ 59 $ — $ — $ 281 Corporate stocks 3 230 — — — 230 Corporate notes and bonds 4 — 877 — — 877 Common/collective funds 5 — — — 462 462 Partnerships 6 — — — 79 79 Registered investment companies 7 48 — — 1 49 Interest bearing cash 48 — — — 48 Other 8 4 103 — — 107 Total $ 552 $ 1,039 $ — $ 542 $ 2,133 Receivables and payables, net (31 ) Combined net plan assets available for benefits $ 2,102 The following table sets forth the VEBA Trust assets for SCE that were accounted for at fair value as of December 31, 2015 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 200 $ 42 $ — $ — $ 242 Corporate stocks 3 222 — — — 222 Corporate notes and bonds 4 — 867 — — 867 Common/collective funds 5 — — — 424 424 Partnerships 6 — — — 93 93 Registered investment companies 7 60 — — 3 63 Interest bearing cash 31 — — — 31 Other 8 5 113 — — 118 Total $ 518 $ 1,022 $ — $ 520 $ 2,060 Receivables and payables, net (24 ) Combined net plan assets available for benefits $ 2,036 1 These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits. 2 Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal Home Loan Mortgage Corporation and the Federal National Mortgage Association. 3 Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 47% ) and the MSCI All Country World Index ( 53% ) for both 2016 and 2015 . 4 Corporate notes and bonds are diversified and include approximately $47 million and $27 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2016 and 2015 , respectively. 5 At December 31, 2016 and 2015 , respectively, 39% and 38% of the common/collective assets are invested in a large cap index fund which seeks to track performance of the Russell 1000 index. 39% and 41% of the remaining assets in this category are in index funds which seek to track performance in the MSCI All Country World Index Investable Market Index and MSCI Europe, Australasia and Far East (EAFE) Index. 18% and 17% in a non-index U.S. equity fund which is actively managed. 6 At December 31, 2016 and 2015 , respectively, 59% and 56% of the partnerships are invested in private equity and venture capital funds. Investment strategies for these funds include branded consumer products, clean and information technology and healthcare. 31% and 21% are invested in a broad range of financial assets in all global markets. 9% and 23% of the remaining partnerships category is invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks. 7 Level 1 registered investment companies consist of a money market fund. 8 Other includes $76 million and $97 million of municipal securities at December 31, 2016 and 2015 , respectively. At December 31, 2016 and 2015 , respectively, approximately 63% and 71% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States. Stock-Based Compensation Edison International maintains a shareholder approved incentive plan (the 2007 Performance Incentive Plan) that includes stock-based compensation. The maximum number of shares of Edison International's common stock authorized to be issued or transferred pursuant to awards under the 2007 Performance Incentive Plan, as amended, is 66 million shares, plus the number of any shares awarded under Edison International's prior plans that are outstanding as of April 26, 2007, which expire, cancel or terminate without being exercised or shares being issued ("carry-over shares"). As of December 31, 2016 , Edison International had approximately 32 million shares remaining available for new award grants under its stock-based compensation plans. The following table summarizes total expense and tax benefits (expense) associated with stock based compensation: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Stock-based compensation expense 1 : Stock options $ 14 $ 14 $ 16 $ 7 $ 8 $ 8 Performance shares 13 7 16 6 4 8 Restricted stock units 6 7 7 3 4 4 Other 1 1 1 — — — Total stock-based compensation expense $ 34 $ 29 $ 40 $ 16 $ 16 $ 20 Income tax benefits related to stock compensation expense $ 41 $ 12 $ 16 $ 20 $ 7 $ 8 Excess tax benefits 2 — 15 15 — 23 20 1 Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income. 2 Reflected in "Settlements of stock-based compensation, net" in the financing section of Edison International's and SCE's consolidated statements of cash flows, "Common stock" in Edison International's consolidated balance sheets and "Additional paid-in capital" in SCE's consolidated balance sheets. Edison International and SCE adopted the new accounting guidance for shared-based payments, see Note 1 for further information. Stock Options Under various plans, Edison International has granted stock options at exercise prices equal to the closing price at the grant date. Prior to 2007, average of the high and low price was used. Edison International may grant stock options and other awards related to, or with a value derived from, its common stock to directors and certain employees. Options generally expire 10 years after the grant date and vest over a period of four years

Investments

Investments	12 Months Ended
	Dec. 31, 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 Date Amortized Cost Fair Value December 31, (in millions) 2016 2015 2016 2015 Stocks — $ 319 $ 304 $ 1,547 $ 1,460 Municipal bonds 2054 659 691 766 840 U.S. government and agency securities 2055 1,131 1,070 1,191 1,128 Corporate bonds 2057 600 708 659 755 Short-term investments and receivables/payables 1 One-year 75 144 79 148 Total $ 2,784 $ 2,917 $ 4,242 $ 4,331 1 Short-term investments include $114 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by January 4, 2017 and January 5, 2016 as of December 31, 2016 and 2015 , respectively. Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion and $1.4 billion at December 31, 2016 and 2015 , respectively. The following table sets forth a summary of changes in the fair value of the trust: Years ended December 31, (in millions) 2016 2015 2014 Balance at beginning of period $ 4,331 $ 4,799 $ 4,494 Gross realized gains 92 326 197 Gross realized losses (19 ) (26 ) (5 ) Unrealized gains (losses) 44 (364 ) 75 Other-than-temporary impairments (36 ) (29 ) (14 ) Interest, dividends and other 116 115 118 Contributions — 54 5 Income taxes (58 ) (64 ) (62 ) Decommissioning disbursements (224 ) (471 ) (4 ) Administrative expenses and other (4 ) (9 ) (5 ) Balance at end of period $ 4,242 $ 4,331 $ 4,799 Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE. Deferred tax liabilities related to net unrealized gains at December 31, 2016 were $348 million . Accordingly, the fair value of Trust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $3.9 billion at December 31, 2016 . Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings. Beginning in 2016, funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts. Acquisitions On December 31, 2015 , Edison Energy acquired three businesses for an aggregate purchase price of approximately $100 million , of which $90 million was allocated to goodwill and identifiable intangibles. Under the terms of the acquisition of one of the agreements, the sellers were entitled to additional consideration (earn-out) in the event that certain financial thresholds were achieved. During the second quarter of 2016, Edison Energy entered into an agreement to buy-out this earn-out provision and recorded an after-tax charge of $13 million . The buy-out was completed, together with modification to employment contracts, in order to align long-term incentive compensation. During 2016, a subsidiary of SoCore Energy agreed to acquire equity interests in solar garden development projects in Minnesota as part of the SunEdison bankruptcy proceedings, subject to certain conditions. The maximum purchase price is $41.9 million if all projects achieve the required conditions. SoCore Energy would also reimburse SunEdison up to $8.7 million of project-specific interconnection costs. Not all of the projects are expected to achieve the closing conditions. Through February 1, 2017 , SoCore Energy acquired four of these development projects ( 28 MWdc) for $10.5 million .

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities Included in SCE's regulatory assets and liabilities are regulatory balancing accounts. CPUC authorized balancing account mechanisms require SCE to refund or recover any differences between forecasted and actual costs. The CPUC has authorized balancing accounts for specified costs or programs such as fuel, purchased-power, demand-side management programs, nuclear decommissioning and public purpose programs. Certain of these balancing accounts include a return on rate base of 7.90% in 2016 and 2015 . The CPUC also authorizes the use of a balancing account to recover from or refund to customers differences in revenue resulting from actual and forecasted electricity sales. Amounts included in regulatory assets and liabilities are generally recorded with corresponding offsets to the applicable income statement accounts. Regulatory Assets SCE's regulatory assets included on the consolidated balance sheets are: December 31, (in millions) 2016 2015 Current: Regulatory balancing accounts $ 135 $ 382 Energy derivatives 150 159 Unamortized investments, net 49 — Other 16 19 Total current 350 560 Long-term: Deferred income taxes, net 4,478 3,757 Pensions and other postretirement benefits 710 849 Energy derivatives 947 1,027 Unamortized investments, net 80 182 San Onofre 857 1,043 Unamortized loss on reacquired debt 184 201 Regulatory balancing accounts 66 36 Environmental remediation 126 129 Other 7 288 Total long-term 7,455 7,512 Total regulatory assets $ 7,805 $ 8,072 SCE's regulatory assets related to energy derivatives are primarily an offset to unrealized losses on derivatives. The regulatory asset changes based on fluctuations in the fair market value of the contracts, in which the original contracts expire in 10 to 45 years. SCE's current and long-term unamortized investments include legacy meters retired as part of the Edison SmartConnect ® program. SCE's unamortized investments related to legacy meters are expected to be recovered by 2017 and earned a rate of return of 6.46% in 2016 and 2015. SCE's regulatory assets related to deferred income taxes represent tax benefits passed through to customers. The CPUC requires SCE to flow through certain deferred income tax benefits to customers by reducing electricity rates, thereby deferring recovery of such amounts to future periods. Based on current regulatory ratemaking and income tax laws, SCE expects to recover its regulatory assets related to deferred income taxes over the life of the assets that give rise to the accumulated deferred income taxes, approximately from 1 to 60 years. SCE's regulatory assets related to pensions and other post-retirement plans represent the unfunded net loss and prior service costs of the plans (see "Pension Plans and Postretirement Benefits Other than Pensions" discussion in Note 8). This amount is being recovered through rates charged to customers. SCE's unamortized investments long-term primarily include nuclear assets related to Palo Verde. Nuclear assets related to Palo Verde are expected to be recovered by 2047 and earned a return of 7.90% in 2016 and 2015. In accordance with the San Onofre OII Settlement Agreement, SCE is authorized to recover in rates its San Onofre regulatory asset, generally over a ten -year period commencing February 1, 2012. Under the San Onofre OII Settlement Agreement (see Note 11), SCE was allowed to earn a rate of return of 2.62% in 2016 and 2015 and is authorized to continue to earn this rate as adjusted during the amortization period thereafter with changes in SCE's authorized return on debt and preferred equity. SCE's regulatory assets related to San Onofre nuclear fuel will earn a return equal to commercial paper rate that the CPUC uses to calculate interest on balancing accounts. In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. See Note 11 for further information. SCE's net regulatory asset related to its unamortized loss on reacquired debt will be recovered over the original amortization period of the reacquired debt over periods ranging from 10 to 35 years. SCE's regulatory assets related to environmental remediation represents a portion of the costs incurred at certain sites that SCE is allowed to recover through customer rates. See "Environmental Remediation" discussed in Note 11. Regulatory Liabilities SCE's regulatory liabilities included on the consolidated balance sheets are: December 31, (in millions) 2016 2015 Current: Regulatory balancing accounts $ 736 $ 1,106 Other 20 22 Total current 756 1,128 Long-term: Costs of removal 2,847 2,781 Recoveries in excess of ARO liabilities 1,639 1,502 Regulatory balancing accounts 1,180 1,314 Other 60 79 Total long-term 5,726 5,676 Total regulatory liabilities $ 6,482 $ 6,804 SCE's regulatory liabilities related to costs of removal represent differences between asset removal costs recorded and amounts collected in rates for those costs. SCE's regulatory liabilities related to recoveries in excess of ARO liabilities represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9. Net Regulatory Balancing Accounts Balancing account over and under collections represent differences between cash collected in current rates for specified forecasted costs and such costs that are actually incurred. Undercollections are recorded as regulatory balancing account assets. Overcollections are recorded as regulatory balancing account liabilities. With some exceptions, SCE seeks to adjust rates on an annual basis or at other designated times to recover or refund the balances recorded in its balancing accounts. Regulatory balancing accounts that SCE does not expect to collect or refund in the next 12 months are reflected in the long-term section of the consolidated balance sheets. Regulatory balancing accounts do not have the right of offset and are presented gross in the consolidated balance sheets. Under and over collections accrue interest based on a three-month commercial paper rate published by the Federal Reserve. The following table summarizes the significant components of regulatory balancing accounts included in the above tables of regulatory assets and liabilities: December 31, (in millions) 2016 2015 Asset (liability) Energy resource recovery account $ (20 ) $ (439 ) New system generation balancing account (6 ) (171 ) Public purpose programs and energy efficiency programs (992 ) (683 ) Base revenue requirement balancing account (426 ) (319 ) Tax accounting memorandum account and pole loading (142 ) (248 ) DOE litigation memorandum account 1 (122 ) — Greenhouse gas auction revenue 31 (75 ) FERC balancing accounts (69 ) 74 Other 31 (141 ) Liability $ (1,715 ) $ (2,002 ) 1 Represents proceeds from the Department of Energy ("DOE") resulting from its failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. Damages recovered are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs. See Note 11 for further discussion.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Third-Party Power Purchase Agreements SCE entered into various agreements, which were approved by the CPUC and met critical contract provisions (including completion of major milestones for construction), to purchase power and electric capacity, including: • Renewable Energy Contracts – California law requires retail sellers of electricity to comply with a RPS by delivering renewable energy, primarily through power purchase contracts. Renewable energy contracts generally contain escalation clauses requiring increases in payments. As of December 31, 2016 , SCE had 119 renewable energy contracts. • QF Power Purchase Agreements – Under the Public Utility Regulatory Policies Act of 1978 ("PURPA"), electric utilities are required, with exceptions, to purchase energy and capacity from independent power producers that are qualifying co-generation facilities and qualifying small power production facilities or QFs. As of December 31, 2016 , SCE had 55 QF contracts. • Other Power Purchase Agreements – SCE has entered into 30 other power purchase agreements, including combined heat and power contracts, tolling arrangements and resource adequacy contracts. At December 31, 2016 , the undiscounted future minimum expected payments for the SCE power purchase agreements that have been approved by the CPUC and have completed major milestones for construction were as follows: (in millions) Renewable Energy Contracts QF Power Purchase Agreements Other Purchase Agreements 2017 $ 1,516 $ 187 $ 769 2018 1,606 148 604 2019 1,704 87 516 2020 1,776 39 472 2021 1,786 16 420 Thereafter 22,811 53 1,258 Total future commitments $ 31,199 $ 530 $ 4,039 The table above includes contractual obligations for power procurement contracts that met the critical contract provisions as of December 31, 2016 in which the term is over a year when it was executed. Additionally, SCE has signed contracts that have not met the critical contract provisions that would increase contractual obligations by $53 million in 2017, $235 million in 2018, $312 million in 2019, $554 million in 2020, $630 million in 2021 and $9.1 billion thereafter, if all principal provisions are completed. Costs incurred for power purchase agreements were $3.3 billion in 2016, $3.2 billion in 2015 and $3.8 billion in 2014, which include costs associated with contracts with terms of less than one year. Many of the power purchase agreements that SCE entered into with independent power producers are accounted for as leases. The following table shows the future minimum lease payments due under the contracts that are treated as operating and capital leases (these amounts are also included in the table above). Due to the inherent uncertainty associated with the reliability of the fuel source, expected purchases from most renewable energy contracts do not meet the definition of a minimum lease payment and have been excluded from the operating and capital lease table below but remain in the table above. The future minimum lease payments for capital leases are discounted to their present value in the table below using SCE's incremental borrowing rate at the inception of the leases. The amount of this discount is shown in the table below as the amount representing interest. (in millions) Operating Leases Capital Leases 2017 $ 341 $ 1 2018 237 1 2019 161 1 2020 146 2 2021 142 2 Thereafter 1,355 9 Total future commitments $ 2,382 $ 16 Amount representing executory costs (7 ) Amount representing interest (2 ) Net commitments $ 7 Operating lease expense for power purchase agreements was $1.9 billion in 2016 , and $1.7 billion in both 2015 and 2014 (including contingent rents of $1.4 billion in 2016 , $1.1 billion in 2015 and $944 million in 2014 ). Contingent rents for capital leases were $109 million in 2016 and less than $1 million in both 2015 and 2014. The timing of SCE's recognition of the lease expense conforms to ratemaking treatment for SCE's recovery of the cost of electricity and is included in purchased power. Other Lease Commitments The following summarizes the estimated minimum future commitments for SCE's non-cancelable other operating leases (excluding SCE's power purchase agreements discussed above): (in millions) Operating Leases – Other 2017 $ 52 2018 46 2019 37 2020 28 2021 22 Thereafter 258 Total future commitments $ 443 Operating lease expense for other leases (primarily related to vehicles, office space and other equipment) were $68 million in 2016 , $80 million in 2015 and $96 million in 2014 . Certain leases on office facilities contain escalation clauses requiring annual increases in rent. The rentals payable under these leases may increase by a fixed amount each year, a percentage over base year, or the customer price index. Other Commitments The following summarizes the estimated minimum future commitments for SCE's other commitments: (in millions) 2017 2018 2019 2020 2021 Thereafter Total Other contractual obligations $ 156 $ 141 $ 103 $ 98 $ 82 $ 631 $ 1,211 Costs incurred for other commitments were $141 million in 2016 , $182 million in 2015 and $90 million in 2014 . SCE has fuel supply contracts for Palo Verde which require payment only if the fuel is made available for purchase. SCE also has commitments related to maintaining reliability and expanding SCE's transmission and distribution system. The table above excludes other contractual obligations that have not met the critical contract provisions. As of December 31, 2016, SCE has signed capacity reduction contracts that have not met critical contract provisions and are, therefore, not included in the table above. These contracts would increase the contractual obligations by $3 million in 2017, $24 million in 2018, $94 million in 2019, $93 million in 2020, $71 million in 2021, and $478 million thereafter, if all principal provisions are completed. The table above does not include asset retirement obligations, which are discussed in Note 1. Indemnities Edison International and SCE have various financial and performance guarantees and indemnity agreements which are issued in the normal course of business. Edison International and SCE have provided indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, and indemnities for specified environmental liabilities and income taxes with respect to assets sold. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated. SCE has indemnified the City of Redlands, California in connection with Mountainview's California Energy Commission permit for cleanup or associated actions related to groundwater contaminated by perchlorate due to the disposal of filter cake at the City's solid waste landfill. The obligations under this agreement are not limited to a specific time period or subject to a maximum liability. SCE has not recorded a liability related to this indemnity. Contingencies In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business. Edison International and SCE believe the outcome of these other proceedings will not, individually or in the aggregate, materially affect its financial position, results of operations and cash flows. San Onofre Related Matters Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3. San Onofre CPUC Proceedings In November 2014, the CPUC approved the San Onofre OII Settlement Agreement, which resolved the CPUC's investigation regarding the steam generator replacement project at San Onofre and the related outages and subsequent shutdown of San Onofre. Subsequently, the San Onofre OII proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned ALJ to consider whether, in light of the Company not reporting certain ex parte communications on a timely basis, the San Onofre OII Settlement Agreement remained reasonable, consistent with the law and in the public interest, which is the standard the CPUC applies in reviewing settlements submitted for approval. In comments filed with the CPUC in July 2016, SCE asserted that the Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the OII, however, have requested that the CPUC either modify the San Onofre OII Settlement Agreement or vacate its previous approval of the settlement and reinstate the OII for further proceedings. In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ expressed concerns about the extent to which the failure to timely report ex parte communications had impacted the settlement negotiations and directed SCE to meet and confer with the other parties in the OII to consider changing the terms of the San Onofre OII Settlement Agreement. The ruling set out a schedule requiring that at least two meet and confer sessions be held in the first quarter of 2017 and requiring the parties to submit a joint status report to the CPUC by April 28, 2017 if no modifications have been agreed to by some or all of the parties as a result of the meet and confer process. SCE has recorded a regulatory asset to reflect the expected recoveries under the San Onofre OII Settlement Agreement. At December 31, 2016, $857 million remains to be collected. Challenges related to the Settlement of San Onofre CPUC Proceedings A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case appealed the dismissal to the Ninth Circuit in May 2015. The Ninth Circuit cancelled the oral argument that had been scheduled for February 9, 2017 and ordered the parties to notify the Ninth Circuit of the status of the San Onofre OII by May 1, 2017 and periodically thereafter. In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its then Chief Financial Officer. The complaint was later amended to include SCE's former President as a defendant. The lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than initially reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International common stock between March 21, 2014 and June 24, 2015. In September 2016, the Court granted defendants' motion to dismiss the complaint, with an opportunity for plaintiff to amend the complaint. Plaintiff filed an amended complaint and defendants again moved to dismiss the complaint in October 2016. Also in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same allegations was filed in August 2015 and was subsequently consolidated with the July 2015 federal derivative lawsuit. In September 2016, the Court granted defendants' motion to dismiss the complaint, with an opportunity for plaintiff to amend the complaint. Plaintiff did not file an amended complaint by the required date. In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the federal derivative lawsuits discussed above. The California state court action is currently on hold in light of the pending federal suits discussed above. In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its Treasurer by an Edison International employee, alleging claims under the Employee Retirement Income Security Act ("ERISA"). The complaint purports to be filed on behalf of a class of Edison International employees who were participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between March 27, 2014 and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew or should have known that investment in the Edison International Stock Fund was imprudent because the price of Edison International common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte communications with CPUC decision-makers related to the San Onofre OII. In July 2016, the federal court granted the defendants' motion to dismiss the lawsuit with an opportunity for the plaintiff to amend her complaint. Plaintiff filed an amended complaint in July 2016 that dismissed Edison International as a named defendant, and the remaining defendants filed a motion to dismiss in August 2016. Defendants' motion was heard by the court in November 2016 and a decision is pending. Edison International and SCE cannot predict the outcome of these proceedings. MHI Claims SCE is also pursuing claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"), which designed and supplied the replacement steam generators. MHI warranted the replacement steam generators for an initial period of 20 years from acceptance and is contractually obligated to repair or replace defective items with dispatch and to pay specified damages for certain repairs. MHI's stated liability under the purchase agreement is limited to $138 million and excludes consequential damages, defined to include "the cost of replacement power;" however, limitations in the contract are subject to applicable exceptions both in the contract and under law. SCE has advised MHI that it believes one or more of such exceptions apply and that MHI's liability is not limited to $138 million . MHI has advised SCE that it disagrees. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce in accordance with the purchase contract seeking damages for all losses. In the request for arbitration, SCE alleges contract and tort claims and seeks at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI has denied any liability and has asserted counterclaims for $41 million , for which SCE has denied any liability. Each of the other San Onofre owners sued MHI, alleging claims arising from MHI's supplying the faulty steam generators. These litigation claims have been stayed pending the arbitration. The other co-owners (San Diego Gas & Electric and Riverside) have been added as additional claimants in the arbitration. The arbitration is being conducted pursuant to a confidentiality order issued by the arbitration panel. Hearings concluded on April 29, 2016. A decision is expected to be issued in the first quarter of 2017. SCE, on behalf of itself and the other San Onofre co-owners, has submitted seven invoices to MHI totaling $149 million for steam generator repair costs incurred through April 30, 2013. MHI paid the first invoice of $45 million , while reserving its right to challenge it and subsequently rejected a portion of the first invoice and has not paid further invoices, claiming further documentation is required, which SCE disputes. SCE recorded its share of the invoice paid (approximately $35 million ) as a reduction of repair and inspection costs in 2012. Under the San Onofre OII Settlement Agreement, recoveries from MHI (including amounts paid by MHI under the first invoice), if any, will first be applied to reimburse costs incurred in pursuing such recoveries, including litigation costs. To the extent SCE's share of recoveries from MHI exceed such costs, they will be allocated 50% to customers and 50% to SCE. The first $282 million of SCE's customers' portion of such recoveries from MHI will be distributed to customers via a credit to a sub-account of SCE's BRRBA, reducing revenue requirements from customers. Amounts in excess of the first $282 million distributable to SCE customers will reduce SCE's regulatory asset represented by the unamortized balance of investment in San Onofre base plant, reducing the revenue requirement needed to amortize such investment. The amortization period, however, will be unaffected. Any additional amounts received after the regulatory asset is recovered will be applied to the BRRBA. The San Onofre OII Settlement Agreement provides the utilities with the discretion to resolve the MHI dispute without CPUC approval, but the utilities are obligated to use their best efforts to inform the CPUC of any settlement or other resolution of these disputes to the extent this is possible without compromising any aspect of the resolution. SCE and SDG&E have also agreed to allow the CPUC to review the documentation of any final resolution of the MHI dispute and the litigation costs incurred in pursuing claims against MHI to ensure they are not exorbitant in relation to the recovery obtained. There is no assurance that there will be any recovery from MHI or that, if there is a recovery, it will equal or exceed the litigation costs incurred to pursue the recovery. Long Beach Service Interruptions In July 2015, SCE's customers who are served via the network portion of SCE's electric system in Long Beach, California experienced service interruptions due to multiple underground vault fires and underground cable failures. No personal injuries were reported in connection with these events. SCE expects to incur penalties as a result of these events. Although resolution will be subject to settlement discussions with SED and CPUC review and approval, SCE has recorded a liability for the estimated loss. Environmental Remediation SCE records its environmental remediation liabilities when site assessments and/or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. SCE reviews its sites and measures the liability quarterly, by assessing a range of reasonably likely costs for each identified site using currently available information, including existing technology, presently enacted laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties. These estimates include costs for site investigations, remediation, operation and maintenance, monitoring and site closure. Unless there is a single probable amount, SCE records the lower end of this reasonably likely range of costs (reflected in "Other long-term liabilities") at undiscounted amounts as timing of cash flows is uncertain. At December 31, 2016 , SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites with a liability balance as of December 31, 2016 , in which the upper end of the range of the costs is at least $1 million ) was $128 million , including $77 million related to San Onofre. In addition to these sites, SCE also has 18 immaterial sites with a liability balance at December 31, 2016 for which the total minimum recorded liability was $3 million . Of the $131 million total environmental remediation liability for SCE, $126 million has been recorded as a regulatory asset. SCE expects to recover $46 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $80 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites. The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $168 million and $8 million , respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes. SCE expects to clean up and mitigate its identified sites over a period of up to 30 years . Remediation costs for each of the next four years are expected to range from $8 million to $20 million . Costs incurred for years ended December 31, 2016, 2015 and 2014 were $4 million , $5 million and $4 million , respectively. Based upon the CPUC's regulatory treatment of environmental remediation costs incurred at SCE, SCE believes that costs ultimately recorded will not materially affect its results of operations, financial position or cash flows. There can be no assurance, however, that future developments, including additional information about existing sites or the identification of new sites, will not require material revisions to estimates. Nuclear Insurance Federal law limits public offsite liability claims for bodily injury and property damage from a nuclear incident to the amount of available financial protection, which is currently approximately $13.4 billion . As of January 1, 2017, SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available ( $450 million ) through a Facility Form issued by American Nuclear Insurers ("ANI"). The balance is covered by a loss sharing program among nuclear reactor licensees. If a nuclear incident at any licensed reactor in the United States results in claims and/or costs which exceed the primary insurance at that plant site, all nuclear reactor licensees could be required to contribute their share of the liability in the form of a deferred premium. The ANI Facility Form coverage includes broad liability protection for bodily injury or offsite property damage caused by the nuclear energy hazard at San Onofre, or while in transit to or from San Onofre. The Facility Form, however, includes several exclusions. First, it excludes onsite property damage to the nuclear facility itself and onsite cleanup costs, but as discussed below SCE maintains separate NEIL property damage coverage for such events. Second, tort claims of onsite workers are excluded, but SCE also maintains an ANI Master Worker Form policy that provides coverage for non-licensee workers. This program provides a shared industry aggregate limit of $450 million . Industry losses covered by this program could reduce limits available to SCE. Third, offsite environmental costs arising out of government orders or directives, including those issued under the Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA, are excluded, with minor exceptions from clearly identifiable accidents. Based on its ownership interests, SCE could be required to pay a maximum of approximately $255 million per nuclear incident. However, it would have to pay no more than approximately $38 million per incident in any one year. If the public liability limit above is insufficient, federal law contemplates that additional funds may be appropriated by Congress. This could include an additional assessment on all licensed reactor operators as a measure for raising further federal revenue. NEIL, a mutual insurance company owned by entities with nuclear facilities, issues nuclear property damage and accidental outage insurance policies. The amount of nuclear property insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $1.06 billion . These policies include coverage for decontamination liability. Property damage insurance also covers damages caused by acts of terrorism up to specified limits. Additional outage insurance covers part of replacement power expenses during an accident-related nuclear unit outage. The accidental outage insurance at San Onofre has been canceled as a result of the permanent retirement, but that insurance continues to be in effect at Palo Verde. If losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $52 million per year. Insurance premiums are charged to operating expense. Wildfire Insurance Severe wildfires in California have given rise to large damage claims against California utilities for fire-related losses alleged to be the result of the failure of electric and other utility equipment. Invoking a California Court of Appeal decision, plaintiffs pursuing these claims have relied on the doctrine of inverse condemnation, which can impose strict liability (including liability for a claimant's attorneys' fees) for property damage. Drought conditions in California have also increased the duration of the wildfire season and the risk of severe wildfire events. SCE has approximately $1 billion of insurance coverage for wildfire liabilities for the period ending on May 31, 2017. SCE has a self-insured retention of $10 million per wildfire occurrence. SCE or its contractors may experience coverage reductions and/or increased insurance costs in future years. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. Spent Nuclear Fuel Under federal law, the DOE is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. Currently, both San Onofre and Palo Verde have interim storage for spent nuclear fuel on site sufficient for their current license period. In June 2010, the United States Court of Federal Claims issued a decision granting SCE and the San Onofre co-owners damages of approximately $142 million (SCE share $112 million ) to recover costs incurred through December 31, 2005 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. SCE received payment from the federal government in the amount of the damage award. In April 2016, SCE, as operating agent, settled a lawsuit on behalf of the San Onofre owners against the DOE for $162 million , including reimbursement for legal costs (SCE share $124 million ) to compensate for damages caused by the DOE's failure to meet its obligation to begin accepting spent nuclear fuel for the period from January 1, 2006 to December 31, 2013. The settlement also provides for a claim submission/audit process for expenses incurred from 2014 – 2016, where SCE will submit a claim for damages caused by the DOE failure to accept spent nuclear fuel each year, followed by a government audit and payment of the claim. This process will make additional legal action to recover damages incurred in 2014 – 2016 unnecessary. The first such claim covering damages for 2014 – 2015 was filed on September 30, 2016 for approximately $56 million . In February 2017, the DOE reviewed the 2014 – 2015 claim submission and reduced the original request to approximately $43 million primarily due to DOE allocation limits. SCE has 30 days to review and accept the DOE's determination. SCE will make the claim submission for 2016 damages in the third quarter of 2017. All damages recovered by SCE are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs.

Preferred and Preference Stock

Preferred and Preference Stock of Utility	12 Months Ended
	Dec. 31, 2016
Stockholders' Equity Note [Abstract]
Preferred and Preference Stock of Utility	Preferred and Preference Stock of Utility SCE's authorized shares are: $100 cumulative preferred – 12 million shares, $25 cumulative preferred – 24 million shares and preference with no par value – 50 million shares. SCE's outstanding shares are not subject to mandatory redemption. There are no dividends in arrears for the preferred or preference shares. Shares of SCE's preferred stock have liquidation and dividend preferences over shares of SCE's common stock and preference stock. All cumulative preferred shares are redeemable. When preferred shares are redeemed, the premiums paid, if any, are charged to common equity. No preferred shares were issued or redeemed in the years ended December 31, 2016 , 2015 and 2014 . There is no sinking fund requirement for redemptions or repurchases of preferred shares. Shares of SCE's preference stock rank junior to all of the preferred stock and senior to all common stock. Shares of SCE's preference stock are not convertible into shares of any other class or series of SCE's capital stock or any other security. There is no sinking fund requirement for redemptions or repurchases of preference shares. Preferred stock and preference stock is: Shares Redemption December 31, (in millions, except shares and per-share amounts) 2016 2015 Cumulative preferred stock $25 par value: 4.08% Series 650,000 $ 25.50 $ 16 $ 16 4.24% Series 1,200,000 25.80 30 30 4.32% Series 1,653,429 28.75 41 41 4.78% Series 1,296,769 25.80 33 33 Preference stock No par value: 6.50% Series D (cumulative) 1,250,000 100.00 — 125 6.25% Series E (cumulative) 350,000 1,000.00 350 350 5.625% Series F (cumulative) 190,004 2,500.00 475 475 5.10% Series G (cumulative) 160,004 2,500.00 400 400 5.75% Series H (cumulative) 110,004 2,500.00 275 275 5.375% Series J (cumulative) 130,004 2,500.00 325 325 5.45% Series K (cumulative) 120,004 2,500.00 300 — SCE's preferred and preference stock 2,245 2,070 Less issuance costs (54 ) (50 ) Edison International's preferred and preference stock of utility $ 2,191 $ 2,020 Shares of Series E preference stock issued in 2012 may be redeemed at par, in whole or in part, on or after February 1, 2022. Shares of Series F, G, H, J and K preference stock, issued in 2012 , 2013 , 2014 , 2015 and 2016, respectively, may be redeemed at par, in whole, but not in part, at any time prior to June 15, 2017, March 15, 2018, March 15, 2024, September 15, 2025 and March 15, 2026, respectively, if certain changes in tax or investment company laws occur. On or after June 15, 2017, March 15, 2018, March 15, 2024, September 15, 2025 and March 15, 2026, SCE may redeem the Series F, G, H, J and K shares, respectively, at par, in whole or in part. For shares of Series H, J and K preference stock, distributions will accrue and be payable at a floating rate from and including March 15, 2024, September 15, 2025 and March 15, 2026, respectively. Shares of Series F, G, H, J and K preference stock were issued to SCE Trust I, SCE Trust II, SCE Trust III, SCE Trust IV and SCE Trust V, respectively, special purpose entities formed to issue trust securities as discussed in Note 3. The proceeds from the sale of the shares of Series K were used to redeem $ 125 million of the Company's Series D preference stock and for general corporate purposes. Preference shares are not subject to mandatory redemption. At December 31, 2016 , declared dividends related to SCE's preferred and preference stock were $12 million .

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss The changes in accumulated other comprehensive loss, net of tax, consist of: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Beginning balance $ (56 ) $ (58 ) $ (22 ) $ (28 ) Pension and PBOP – net gain (loss): Other comprehensive (loss) income before reclassifications (4 ) (8 ) (2 ) 1 Reclassified from accumulated other comprehensive loss 1 6 10 3 5 Other 1 — 1 — Change 3 2 2 6 Ending balance $ (53 ) $ (56 ) $ (20 ) $ (22 ) 1 These items are included in the computation of net periodic pension and PBOP expense. See Note 8 for additional information.

Interest and Other Income and O

Interest and Other Income and Other Expenses	12 Months Ended
	Dec. 31, 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: Years ended December 31, (in millions) 2016 2015 2014 SCE interest and other income: Equity allowance for funds used during construction $ 74 $ 87 $ 65 Increase in cash surrender value of life insurance policies and life insurance benefits 39 26 36 Interest income 3 4 5 Other 7 6 16 Total SCE interest and other income 123 123 122 Other income of Edison International Parent and Other 1 — 51 25 Total Edison International interest and other income $ 123 $ 174 $ 147 SCE other expenses: Civic, political and related activities and donations $ (32 ) $ (35 ) $ (35 ) Other (12 ) (24 ) (44 ) Total SCE other expenses (44 ) (59 ) (79 ) Other expense of Edison International Parent and Other — — (1 ) Total Edison International other expenses $ (44 ) $ (59 ) $ (80 ) 1 Reflects Edison Capital's income related to the sale of affordable housing projects for the year ended December 31, 2015.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations EME Chapter 11 Bankruptcy In December 2012, EME and certain of its wholly-owned subsidiaries filed voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of Illinois, Eastern Division. The Amended Plan of Reorganization, including the EME Settlement Agreement, was completed on April 1, 2014 with the sale of substantially all of EME's assets to NRG Energy, Inc. and the transactions called for in the EME Settlement Agreement, including an initial cash payment to the Reorganization Trust of $225 million in April 2014. In August 2014, Edison International entered into an amendment of the EME Settlement Agreement that finalized the remaining matters related to the EME Settlement including setting the amount of the two installment payments. Edison International made an installment payment of $204 million in September 2015 and made the remaining $214 million payment in September 2016. Income from discontinued operations, net of tax, was $12 million (pre-tax income of $1 million ), $35 million (pre-tax income of $15 million ) and $185 million (pre-tax loss of $525 million ) for the years ended December 31, 2016 , 2015 and 2014 , respectively. The 2016 and 2015 income was primarily related to the resolution of tax issues related to EME. The 2015 income also included insurance recoveries. Results from discontinued operations in 2014 consisted of a pre-tax loss of $525 million primarily related to liabilities assumed in connection with the EME Settlement Agreement, including the payments to the Reorganization Trust discussed above, and income tax benefits of $710 million related to the EME net operating loss and other credit carryforwards.

Supplemental Cash Flows Informa

Supplemental Cash Flows Information	12 Months Ended
	Dec. 31, 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 Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Cash payments (receipts) for interest and taxes: Interest, net of amounts capitalized $ 504 $ 512 $ 504 $ 475 $ 478 $ 487 Tax payments (refunds), net 18 1 32 78 144 (88 ) Non-cash financing and investing activities: Dividends declared but not paid: Common stock $ 177 $ 156 $ 136 $ — $ — $ 147 Preferred and preference stock 12 14 18 12 14 18 Details of debt exchange: Pollution-control bonds redeemed (2.875%) — (203 ) — — (203 ) — Pollution-control bonds issued (1.875%) — 203 — — 203 — Notes issued under EME Settlement Agreement $ — $ — $ 418 $ — $ — $ — SCE's accrued capital expenditures at December 31, 2016 , 2015 and 2014 were $540 million , $543 million , and $837 million , respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid. During 2015, SCE amended a power contract classified as a capital lease, which resulted in a reduction in the lease obligation and asset by $ 147 million .

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Related-Party Transactions Edison International and SCE provide and receive various services to and from its subsidiaries and affiliates. Services provided to Edison International by SCE are priced at fully loaded cost (i.e., direct cost of good or service and allocation of overhead cost). Specified administrative services such as payroll, employee benefit programs, all performed by Edison International or SCE employees, are shared among all affiliates of Edison International. Costs are allocated based on one of the following formulas: percentage of time worked, equity in investment and advances, number of employees, or multi-factor (operating revenues, operating expenses, total assets and number of employees). Edison International allocates various corporate administrative and general costs to SCE and other subsidiaries using established allocation factors.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited) Edison International's quarterly financial data is as follows: 2016 (in millions, except per-share amounts) Total Fourth Third Second First Operating revenue $ 11,869 $ 2,884 $ 3,767 $ 2,777 $ 2,440 Operating income 2,092 566 695 381 448 Income from continuing operations 1 1,413 347 451 310 305 Income (loss) from discontinued operations, net 12 13 — (2 ) 1 Net income attributable to common shareholders 1 1,311 329 421 280 281 Basic earnings (loss) per share 1 : Continuing operations $ 3.99 $ 0.97 $ 1.29 $ 0.87 $ 0.86 Discontinued operations 0.03 0.04 — (0.01 ) — Total $ 4.02 $ 1.01 $ 1.29 $ 0.86 $ 0.86 Diluted earnings (loss) per share 1 : Continuing operations $ 3.94 $ 0.96 $ 1.27 $ 0.86 $ 0.85 Discontinued operations 0.03 0.04 — (0.01 ) — Total $ 3.97 $ 1.00 $ 1.27 $ 0.85 $ 0.85 Dividends declared per share 1.9825 0.5425 0.4800 0.4800 0.4800 Common stock prices: High $ 78.72 $ 73.81 $ 78.72 $ 77.71 $ 72.34 Low 57.97 67.44 71.31 67.71 57.97 Close 71.99 71.99 72.25 77.67 71.89 1 Edison International adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income from continuing operations, as previously reported, was $449 million for the third quarter of 2016, $306 million for the second quarter of 2016 and $295 million for the first quarter of 2016. Net income attributable to common shareholders, as previously reported, was $419 million for the third quarter of 2016, $276 million for the second quarter of 2016 and $271 million for the first quarter of 2016. Basic EPS for continuing operations, as previously reported, was $1.29 for the third quarter of 2016, $0.86 for the second quarter of 2016 and $0.83 for the first quarter of 2016. Diluted EPS for continuing operations, as previously reported, was $1.27 for the third quarter of 2016, $0.85 for the second quarter of 2016 and $0.82 for the first quarter of 2016. 2015 (in millions, except per-share amounts) Total Fourth Third Second First Operating revenue $ 11,524 $ 2,341 $ 3,763 $ 2,908 $ 2,512 Operating income 2,008 340 608 524 538 Income (loss) from continuing operations 1 1,082 (47 ) 405 406 318 Income (loss) from discontinued operations, net 35 (8 ) 43 — — Net income (loss) attributable to common shareholders 1,020 (79 ) 421 379 299 Basic earnings (loss) per share: Continuing operations $ 3.02 $ (0.22 ) $ 1.16 $ 1.16 $ 0.92 Discontinued operations 0.11 (0.02 ) 0.13 — — Total $ 3.13 $ (0.24 ) $ 1.29 $ 1.16 $ 0.92 Diluted earnings (loss) per share: Continuing operations $ 2.99 $ (0.22 ) $ 1.15 $ 1.15 $ 0.91 Discontinued operations 0.11 (0.02 ) 0.13 — — Total $ 3.10 $ (0.24 ) $ 1.28 $ 1.15 $ 0.91 Dividends declared per share 1.7325 0.4800 0.4175 0.4175 0.4175 Common stock prices: High $ 69.59 $ 66.29 $ 63.18 $ 64.55 $ 69.59 Low 55.18 57.51 55.52 55.18 61.02 Close 59.21 59.21 63.07 55.58 62.47 1 In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions. SCE's quarterly financial data is as follows: 2016 (in millions) Total Fourth Third Second First Operating revenue $ 11,830 $ 2,874 $ 3,752 $ 2,768 $ 2,435 Operating income 2,217 594 721 429 472 Net income 1 1,499 359 466 349 325 Net income available for common stock 1 1,376 328 435 318 295 Common dividends declared 701 191 170 170 170 1 SCE adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income, as previously reported, was $466 million for the third quarter of 2016, $346 million for the second quarter of 2016 and $317 million for the first quarter of 2016. Net income available for common stock, as previously reported, was $435 million for the third quarter of 2016, $315 million for the second quarter of 2016 and $287 million for the first quarter of 2016. 2015 (in millions) Total Fourth Third Second First Operating revenue $ 11,485 $ 2,319 $ 3,757 $ 2,901 $ 2,508 Operating income 2,080 366 626 536 550 Net income 1 1,111 (51 ) 417 412 333 Net income available for common stock 998 (80 ) 389 384 305 Common dividends declared 611 170 147 147 147 1 In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions. Due to the seasonal nature of Edison International and SCE's business, a significant amount of revenue and earnings are recorded in the third quarter of each year. As a result of rounding, the total of the four quarters does not always equal the amount for the year.

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information of Parent	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I - Condensed Financial Information of Parent	EDISON INTERNATIONAL SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT CONDENSED BALANCE SHEETS December 31, (in millions) 2016 2015 Assets: Cash and cash equivalents $ 6 $ 7 Other current assets 261 259 Total current assets 267 266 Investments in subsidiaries 13,459 12,696 Deferred income taxes 646 626 Other long-term assets 108 110 Total assets $ 14,480 $ 13,698 Liabilities and equity: Short-term debt $ 539 $ 646 Current portion of long-term debt 400 214 Other current liabilities 484 368 Total current liabilities 1,423 1,228 Long-term debt 397 398 Other long-term liabilities 664 704 Total equity 11,996 11,368 Total liabilities and equity $ 14,480 $ 13,698 EDISON INTERNATIONAL SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT CONDENSED STATEMENTS OF INCOME For the Years Ended December 31, 2016 , 2015 and 2014 (in millions) 2016 2015 2014 Interest income from affiliates $ 6 $ 3 $ 3 Operating expenses and interest expense 86 78 94 Loss before equity in earnings of subsidiaries (80 ) (75 ) (91 ) Equity in earnings of subsidiaries 1,337 1,025 1,482 Income before income taxes 1,257 950 1,391 Income tax benefit (42 ) (35 ) (36 ) Income from continuing operations 1,299 985 1,427 Income from discontinued operations, net of tax 12 35 185 Net income $ 1,311 $ 1,020 $ 1,612 CONDENSED STATEMENTS OF COMPREHENSIVE INCOME For the Years Ended December 31, 2016 , 2015 and 2014 (in millions) 2016 2015 2014 Net income $ 1,311 $ 1,020 $ 1,612 Other comprehensive income (loss), net of tax 3 2 (45 ) Comprehensive income $ 1,314 $ 1,022 $ 1,567 EDISON INTERNATIONAL SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2016 , 2015 and 2014 (in millions) 2016 2015 2014 Net cash provided by (used in) operating activities $ 493 $ 641 $ (73 ) Cash flows from financing activities: Long-term debt issued 400 — — Long-term debt issuance costs (3 ) — — Payable due to affiliates 34 54 66 Short-term debt financing, net (108 ) 26 584 Settlements of stock-based compensation, net (44 ) (42 ) (24 ) Dividends paid (626 ) (544 ) (463 ) Net cash (used in) provided by financing activities (347 ) (506 ) 163 Capital contributions to affiliate (147 ) (30 ) (35 ) Loans to affiliate — (106 ) (60 ) Net cash used in investing activities: (147 ) (136 ) (95 ) Net decrease in cash and cash equivalents (1 ) (1 ) (5 ) Cash and cash equivalents, beginning of year 7 8 13 Cash and cash equivalents, end of year $ 6 $ 7 $ 8 Note 1. Basis of Presentation The accompanying condensed financial statements of Edison International Parent should be read in conjunction with the consolidated financial statements and notes thereto of Edison International and subsidiaries ("Registrant") included in this Form 10-K. Edison International's Parent significant accounting policies are consistent with those of the Registrant, SCE and other wholly owned and controlled subsidiaries. Dividends Received Edison International Parent received cash dividends from SCE of $701 million , $758 million and $378 million in 2016 , 2015 and 2014 , respectively. Dividend Restrictions The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above the 48% on a 13 -month weighted average basis. At December 31, 2016 , SCE's 13 -month weighted-average common equity component of total capitalization was 50.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $585 million , resulting in a restriction on SCE's net assets of $13.9 billion . Note 2. Debt and Credit Agreements Long-Term Debt During the first quarter of 2016, Edison International Parent issued $400 million of 2.95% senior notes due in 2023 . The proceeds from these bonds were used to repay commercial paper borrowings and for general corporate purposes. In addition, at December 31, 2016 and 2015 , Edison International Parent had 3.75% senior notes outstanding of $ 400 million , which matures in 2017 . Credit Agreements and Short-Term Debt During the third quarter of 2016, Edison International Parent amended the credit facility to extend the maturity date for the $1.25 billion credit facility to July 2021. At December 31, 2016 , the outstanding commercial paper was $538 million at a weighted-average interest rate of 0.97% . This short-term debt was supported by the $1.25 billion multi-year revolving credit facility. At December 31, 2015 , the outstanding commercial paper was $646 million at a weighted-average interest rate of 0.78% . The following table summarizes the status of the credit facility at December 31, 2016 : (in millions) Commitment $ 1,250 Outstanding borrowings (538 ) Amount available $ 712 The debt covenant in Edison International's credit facility requires a consolidated debt to total capitalization ratio of less than or equal to 0.65 to 1 . At December 31, 2016 , Edison International's consolidated debt to total capitalization ratio was 0.47 to 1 . Note 3. Related-Party Transactions Edison International's Parent expense from services provided by SCE was $3 million annually in 2016, 2015 and 2014. Edison International's Parent interest expense from loans due to affiliates was $3 million in 2016, $6 million in 2015 and $1 million in 2014. Edison International Parent had current related-party receivables of $262 million and $252 million and current related-party payables of $221 million and $149 million at December 31, 2016 and 2015 , respectively. Edison International Parent had long-term related-party receivables of $103 million and $105 million at December 31, 2016 and 2015 , respectively, and long-term related-party payables of $243 million and $213 million at December 31, 2016 and 2015 , respectively. Note 4. Contingencies For a discussion of material contingencies see "Notes to Consolidated Financial Statements—Note 7. Income Taxes," "—Note 11. Commitments and Contingencies."

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	EDISON INTERNATIONAL SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS Additions (in millions) Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period For the Year ended December 31, 2016 Allowance for uncollectible accounts Customers $ 46.2 $ 17.7 $ — $ 22.7 $ 41.2 All others 15.5 15.9 — 10.8 20.6 Total allowance for uncollectible amounts $ 61.7 $ 33.6 $ — $ 33.5 a $ 61.8 Tax valuation allowance $ 32.0 $ — $ — $ 8.0 d $ 24.0 For the Year ended December 31, 2015 Allowance for uncollectible accounts Customers $ 48.9 $ 23.9 $ — $ 26.6 $ 46.2 All others 23.3 18.0 — 25.8 15.5 Total allowance for uncollectible amounts $ 72.2 $ 41.9 $ — $ 52.4 a $ 61.7 Tax valuation allowance $ 29.0 $ 3.0 $ — $ — $ 32.0 For the Year ended December 31, 2014 Allowance for uncollectible accounts Customers $ 52.2 $ 24.1 $ — $ 27.4 $ 48.9 All others 17.8 19.7 — 14.2 23.3 Total allowance for uncollectible amounts $ 70.0 $ 43.8 $ — $ 41.6 a $ 72.2 Tax valuation allowance $ 1,380.0 b $ — $ — $ 1,351.0 c $ 29.0 a Accounts written off, net. b Edison International recorded deferred tax assets of $2.2 billion related to net operating losses and tax carryforwards that pertain to Edison International's consolidated or combined federal and state tax returns, including approximately $1.6 billion related to EME. Edison International continues to consolidate EME for federal and certain combined state tax returns. EME's Plan of Reorganization, filed in December 2013 ("December Plan of Reorganization"), provides for the transfer of EIX's ownership interest to the creditors, which would result in a tax deconsolidation of EME. Under federal and state tax regulations, the tax deconsolidation of EME would reduce the amounts of net operating loss and tax credits carryforwards that Edison International would be eligible to use in future periods. As a result of the EME's December Plan of Reorganization, which would result in a tax deconsolidation of EME, Edison International has recorded a $1.380 billion valuation allowance based on the estimated amount of such benefits as calculated under the applicable federal and state tax regulations as of December 31, 2013. The deferred income tax benefits recognized by Edison International less the valuation allowance for amounts that would no longer be available upon tax deconsolidation of EME was approximately $220 million . c On April 1, 2014, under the Amended Plan of Reorganization, EME emerged from bankruptcy free of liabilities but remained an indirect wholly-owned subsidiary of Edison International, which will continue to be consolidated with Edison International for income tax purposes. Edison International anticipates realization of the federal and California tax benefits before they expire. Therefore, the valuation allowance on federal and California tax benefits that Edison International recorded in 2013 was released in 2014. The remaining valuation allowance is related to non California state tax benefits. d In 2016, Edison International determined that $8 million of the assets subject to a valuation allowance, had no expectation of recovery and were written off. SOUTHERN CALIFORNIA EDISON COMPANY SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS Additions (in millions) Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period For the Year ended December 31, 2016 For the Year ended Customers $ 46.2 $ 17.0 $ — $ 22.7 $ 40.5 All others 15.5 15.9 — 10.8 20.6 Total allowance for uncollectible accounts $ 61.7 $ 32.9 $ — $ 33.5 a $ 61.1 For the Year ended December 31, 2015 Allowance for uncollectible accounts Customers $ 48.9 $ 23.9 $ — $ 26.6 $ 46.2 All others 18.7 18.0 — 21.2 15.5 Total allowance for uncollectible accounts $ 67.6 $ 41.9 $ — $ 47.8 a $ 61.7 For the Year ended December 31, 2014 Allowance for uncollectible accounts Customers $ 52.2 $ 24.1 $ — $ 27.4 $ 48.9 All others 13.3 19.6 — 14.2 18.7 Total allowance for uncollectible accounts $ 65.5 $ 43.7 $ — $ 41.6 a $ 67.6 a Accounts written off, net.

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 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 holding company for subsidiaries engaged in pursuing competitive business opportunities across energy services and distributed solar for commercial and industrial customers. Such business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutility subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements. Edison International's and SCE's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission ("CPUC") and the Federal Energy Regulatory Commission ("FERC"). SCE applies authoritative guidance for rate-regulated enterprises to the portion of its operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. SCE assesses, at the end of each reporting period, whether regulatory assets are probable of future recovery. See Note 10 for composition of regulatory assets and liabilities.
Use of Estimates	The preparation of financial statements in conformity with United States generally accepted accounting principles ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates.
Cash Equivalents	Cash Equivalents Cash equivalents includes investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less.
Restricted Cash	Cash is temporarily invested until required for check clearing.
Allowance for Uncollectible Accounts	Allowance for Uncollectible Accounts Allowances for uncollectible accounts are provided based upon a variety of factors, including historical amounts written-off, current economic conditions and assessment of customer collectability.
Inventory	Inventory SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at average cost.
Emission Allowances	Emission Allowances SCE is allocated greenhouse gas ("GHG") allowances annually which it is then required to sell into quarterly auctions. GHG proceeds from the auctions are recorded as a regulatory liability to be refunded to customers. SCE purchases GHG allowances in quarterly auctions or from counterparties to satisfy its GHG emission compliance obligations and recovers such costs of GHG allowances from customers. GHG allowances held for use are classified as "Other current assets" on the consolidated balance sheets and are stated, similar to an inventory method, at the lower of weighted-average cost or market.
Property, Plant and Equipment	Property, Plant and Equipment SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, pension and benefits, and property taxes are capitalized as part of plant additions. The CPUC authorizes a rate for each of the indirect costs which are allocated to each project based on either labor or total costs. Estimated useful lives (authorized by the CPUC) and weighted-average useful lives of SCE's property, plant and equipment, are as follows: Estimated Useful Lives Weighted-Average Useful Lives Generation plant 10 years to 57 years 38 years Distribution plant 20 years to 60 years 43 years Transmission plant 40 years to 65 years 53 years General plant and other 5 years to 60 years 22 years Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. Depreciation expense was $1.52 billion , $1.42 billion and $1.33 billion for 2016 , 2015 and 2014 , respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.8% , 3.9% and 4.0% for 2016 , 2015 and 2014 , respectively. Replaced or retired property costs are charged to accumulated depreciation. Nuclear fuel for the Palo Verde Nuclear Power Plant ("Palo Verde") is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. Nuclear fuel is amortized using the units of production method. AFUDC represents the estimated cost of debt and equity funds that finance utility-plant construction and is capitalized during certain plant construction. AFUDC is recovered in rates through depreciation expense over the useful life of the related asset. AFUDC equity represents a method to compensate SCE for the estimated cost of equity used to finance utility plant additions and is recorded as part of construction in progress. AFUDC equity was $74 million , $87 million and $65 million in 2016 , 2015 and 2014 , respectively, and is reflected in "Interest and other income." AFUDC debt was $23 million , $31 million and $25 million in 2016 , 2015 and 2014 , respectively and is reflected as a reduction of "Interest expense." Major Maintenance Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair value is determined via market, cost and income based valuation techniques, as appropriate. SCE's impaired assets are recorded as a regulatory asset if it is deemed probable that such amounts will be recovered from customers.
Goodwill	Goodwill Edison International assesses goodwill through annual goodwill impairment tests, at the reporting unit level, as of October 1st of each year. The fair value of the Edison Energy and SoCore Energy reporting units exceeded their carrying values at the date of the annual impairment analysis.
Nuclear Decommissioning and Asset Retirement Obligations	Nuclear Decommissioning and Asset Retirement Obligations The fair value of a liability for an asset retirement obligation ("ARO") is recorded in the period in which it is incurred, including a liability for the fair value of a conditional ARO, if the fair value can be reasonably estimated even though uncertainty exists about the timing and/or method of settlement. When an ARO liability is initially recorded, SCE capitalizes the cost by increasing the carrying amount of the related long-lived asset. For each subsequent period, the liability is increased for accretion expense and the capitalized cost is depreciated over the useful life of the related asset. AROs related to decommissioning of SCE's nuclear power facilities are based on site-specific studies conducted as part of each Nuclear Decommissioning Cost Triennial Proceeding ("NDCTP") conducted before the CPUC. Revisions of an ARO are established for updated site-specific decommissioning cost estimates. SCE adjusts its nuclear decommissioning obligation into a nuclear-related ARO regulatory asset and also records an ARO regulatory liability as a result of timing differences between the recognition of costs and the recovery of costs through the ratemaking process. For further discussion, see Notes 9 and 10. SCE has not recorded an asset retirement obligation for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities. The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde: December 31, (in millions) 2016 2015 Beginning balance $ 2,762 $ 2,819 Accretion 1 157 173 Revisions (165 ) (14 ) Liabilities settled (168 ) (216 ) Ending balance $ 2,586 $ 2,762 1 An ARO represents the present value of a future obligation. Accretion is an increase in the liability to account for the time value of money resulting from discounting. The recorded liability to decommission SCE's nuclear power facilities (included in the table above) is $2.5 billion as of December 31, 2016. In 2016, SCE updated the recorded liability for Palo Verde and San Onofre Unit 1 based on the 2013 decommissioning study performed for Palo Verde and the 2014 study for San Onofre Unit 1. The recorded liability for San Onofre Unit 2 and 3 is based on a 2014 decommissioning study which followed the decision to permanently retire San Onofre. The 2015 NDTCP filing is expected to be updated for San Onofre Units 2 and 3 after onboarding the decommissioning general contractor and the subsequent development of a new decommissioning cost estimate during 2017. Decommissioning costs, which are recovered through customer rates over the term of each nuclear facility's operating license, are recorded as a component of depreciation expense, with a corresponding credit to the ARO regulatory liability. Amortization of the ARO asset (included within the unamortized nuclear investment) and accretion of the ARO liability are deferred as increases to the ARO regulatory liability account, resulting in no impact on earnings. SCE has collected in rates amounts for the future costs of removal of its nuclear assets, and has placed those amounts in independent trusts. The cost of removal amounts, in excess of amounts collected for assets not legally required to be removed, are classified as regulatory liabilities. Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $6.3 billion through 2079 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 1.7% to 7.5% (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 2.4% to 4.1% . Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts. If the assumed return on trust assets is not earned or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates. See Note 9 for further information. Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceeding. SCE's nuclear decommissioning trust investments primarily consist of fixed income and equity investments that are classified as available-for-sale. Due to regulatory mechanisms, earnings and realized gains and losses (including other-than-temporary impairments) have no impact on electric utility revenue. Unrealized gains and losses on decommissioning trust funds increase or decrease the trust assets and the related regulatory asset or liability and have no impact on electric utility revenue or decommissioning expense. SCE reviews each security for other-than-temporary impairment on the last day of each month. If the fair value on the last day of two consecutive months is less than the cost for that security, SCE recognizes a loss for the other-than-temporary impairment. If the fair value is greater or less than the cost for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively.
Deferred Financing Costs	Deferred Financing Costs Debt premium, discount and issuance expenses incurred in connection with obtaining financing are deferred and amortized on a straight-line basis. Under CPUC ratemaking procedures, SCE's debt reacquisition expenses are amortized over the remaining life of the reacquired debt or, if refinanced, the life of the new debt.
Revenue Recognition	Revenue Recognition Revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the end of each reporting period and reflected in "Operating revenue" on the consolidated statements of income. Rates charged to customers are based on CPUC- and FERC-authorized revenue requirements. CPUC rates are implemented subsequent to final approval. CPUC rates decouple authorized revenue from the volume of electricity sales. Differences between amounts collected and authorized levels are either collected from or refunded to customers, and therefore, SCE earns revenue equal to amounts authorized. FERC rates also decouple revenue from volume of electricity sales. In November 2013, the FERC approved a formula rate effective January 1, 2012 to determine SCE's FERC transmission revenue requirement, including its construction work in progress ("CWIP") revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. Differences between amounts collected and determined under the formula rate are either collected from or refunded to customers, and therefore, SCE earns revenue based on estimates of recorded rate base costs under the FERC formula rate. SCE bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which SCE pays to various municipalities (based on contracts with these municipalities) in order to operate within the limits of the municipality. SCE bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SCE's ability to collect from the customer, are accounted for on a gross basis and reflected in electric utility revenue and other operation and maintenance expense.
Power Purchase Agreements	Power Purchase Agreements SCE enters into power purchase agreements in the normal course of business. A power purchase agreement may be considered a variable interest in a variable interest entity. Under this classification, the power purchase agreement is evaluated to determine if SCE is the primary beneficiary in the variable interest entity, in which case, such entity would be consolidated. None of SCE's power purchase agreements resulted in consolidation of a variable interest entity at December 31, 2016 and 2015 . See Note 3 for further discussion of power purchase agreements that are considered variable interests. A power purchase agreement may also contain a lease for accounting purposes. This generally occurs when a power purchase agreement (signed or modified after June 30, 2003) designates a specific power plant in which the buyer purchases substantially all of the output and does not otherwise meet a fixed price per unit of output exception. SCE has a number of power purchase agreements that contain leases. SCE's recognition of lease expense conforms to the ratemaking treatment for SCE's recovery of the cost of electricity and is recorded in purchased power. See Note 11 for further discussion of SCE's power purchase agreements, including agreements that are classified as operating and capital leases for accounting purposes. A power purchase agreement that does not contain a lease may be classified as a derivative subject to a normal purchase and sale exception, in which case the power purchase agreement is classified as an executory contract and accounted for on an accrual basis. SCE purchases power under certain contracts that are not eligible for the normal purchase and sale exception and are recorded as a derivative on the consolidated balance sheets at fair value. Most of SCE's qualifying facilities ("QFs") contracts are not required to be recorded on the consolidated balance sheets because they either do not meet the definition of a derivative or meet the normal purchase and sale exception. See Note 6 for further information on derivative instruments. Power purchase agreements that do not meet the above classifications are accounted for on an accrual basis.
Derivatives Instruments	Derivative Instruments SCE records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value unless otherwise exempted from derivative treatment as normal purchases or sales. The normal purchases and sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business. Realized gains and losses from SCE's derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, therefore, SCE's fair value changes have no impact on purchased-power expense or earnings. SCE does not use hedge accounting for derivative transactions due to regulatory accounting treatment. Where SCE's derivative instruments are subject to a master netting agreement and certain criteria are met, SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets. In addition, derivative positions are offset against margin and cash collateral deposits. The results of derivative activities are recorded as part of cash flows from operating activities on the consolidated statements of cash flows. See Note 6 for further information on derivative instruments.
Leases	Leases SCE enters into power purchase agreements that may contain leases, as discussed under "Power Purchase Agreements" above. SCE has also entered into a number of agreements to lease property and equipment in the normal course of business. Minimum lease payments under operating leases are levelized (total minimum lease payments divided by the number of years of the lease) and recorded as rent expense over the terms of the leases. Lease payments in excess of the minimum are recorded as rent expense in the year incurred. Capital leases are reported as long-term obligations on the consolidated balance sheets in "Other deferred credits and other long-term liabilities." As a rate-regulated enterprise, SCE's capital lease amortization expense and interest expense are reflected in "Purchased power and fuel" on the consolidated statements of income.
Stock-Based Compensation	Stock-Based Compensation Stock options, performance shares, deferred stock units and restricted stock units have been granted under Edison International's long-term incentive compensation programs. Generally, Edison International does not issue new common stock for settlement of equity awards. Rather, a third party is used to purchase shares from the market and deliver such shares for the settlement of option exercises, performance shares, deferred stock units and restricted stock units. Performance shares awarded in 2014 that are earned are settled half in cash and half in common stock, while the performance shares awarded in 2016 and 2015 that are earned are settled solely in cash. Deferred stock units and restricted stock units are settled in common stock; however, Edison International will substitute cash awards to the extent necessary to pay tax withholding or any government levies. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. For awards granted to retirement-eligible participants stock compensation expenses are recognized on a prorated basis over the initial year or over the period between the date of grant and the date the participant first becomes eligible for retirement. Under new accounting guidance adopted in 2016, share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created.
SCE Dividend Restrictions	SCE Dividend Restrictions The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above 48% on a 13 -month weighted average basis.
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.
Income Taxes	Income Taxes Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets. Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Investment tax credits are deferred and amortized to income tax expense over the lives of the properties or the term of the power purchase agreement of the respective project. Interest income, interest expense and penalties associated with income taxes are reflected in "Income tax expense" on the consolidated statements of income. Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its subsidiaries. Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis.
Redeemable Noncontrolling Interest	Redeemable Noncontrolling Interest Redeemable noncontrolling interest represents the portion of equity ownership in an entity that is not attributable to the equity holders of Edison International and which have rights to put their ownership back to a subsidiary of Edison International. Noncontrolling interest is initially recorded at fair value and is subsequently adjusted for income allocated to the noncontrolling interest and any distributions paid to the noncontrolling interest.
New Accounting Guidance	New Accounting Guidance Accounting Guidance Adopted In April 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct reduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At December 31, 2016, the amount of debt issuance costs that are reflected as a reduction of "Long-term debt" was $71 million for SCE and $81 million for Edison International. At December 31, 2015, the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a reduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International. In April 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements. In May 2015, the FASB issued an accounting standards update which removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using net asset value per share or its equivalent as a practical expedient. Edison International and SCE adopted in the fourth quarter of 2016. Certain prior year amounts have been retrospectively adjusted. In March 2016, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Under this new guidance, the tax effects related to share based payments are recorded through the income statement. Previously, tax benefits in excess of compensation cost ("windfalls") were recorded in equity, and tax deficiencies ("shortfalls") were recorded in equity to the extent of previous windfalls, and then to the income statement. In addition, as part of this new guidance an entity recognizes excess tax benefits regardless of whether the benefit reduces taxes payable in the current period, subject to normal valuation allowance considerations. Edison International and SCE adopted this guidance in the fourth quarter of 2016 using the modified retrospective approach, effective January 1, 2016. As a result, all excess tax benefits resulting from 2016 stock option exercises were reflected in the income statement. Income tax expense for Edison International and SCE was reduced by approximately $28 million and $13 million , respectively, for the year ended December 31, 2016. In addition, Edison International and SCE recorded an increase to beginning retained earnings for pre-2016 stock option exercises that had not been previously recorded in equity ( $42 million and $6 million for Edison International and SCE, respectively). On a prospective basis, the excess tax benefits are classified as an operating activity along with other income tax cash flows on the statement of cash flows. Accruals of compensation costs are based on the number of awards that are expected to vest. Edison International and SCE made an accounting policy election to continue to estimate the number of awards that are expected to vest rather than account for forfeitures when they occur. Accounting Guidance Not Yet Adopted In May 2014, the FASB issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. This standard will be adopted on January 1, 2018. Edison International and SCE have completed the preliminary phases of their assessment of the impact on the consolidated financial statements and do not believe the adoption of this standard will have a material impact on the results of operations. Edison International and SCE anticipate adopting the standard using the modified retrospective application which means that Edison International and SCE would recognize the cumulative effect of initially applying the revenue standard as an adjustment to the opening balance of retained earnings in 2018. In January 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net income. It also amends certain disclosure requirements associated with the fair value of financial instruments. In addition, the new guidance requires financial assets and financial liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of financial asset. Edison International and SCE will adopt this guidance effective January 1, 2018. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's consolidated financial statements. In February 2016, the FASB issued an accounting standards update related to lease accounting including enhanced disclosures. Under the new standard, a lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. Lessees will need to recognize leases on the balance sheet as a right-of-use asset and a related lease liability, and classify the leases as either operating or finance. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. Operating leases will result in straight-line expense while finance leases will result in a higher initial expense pattern due to the interest component. SCE, as a regulated entity, is permitted to continue to have straight-line expense for finance leases, assuming the rate recovery is based upon current payments. Lessees can elect to exclude from the balance sheet short-term contracts one year or less. This guidance is effective January 1, 2019. Early adoption is permitted, but Edison International and SCE do not expect to elect early adoption. The adoption of this standard is expected to increase right-of-use assets and lease liabilities in Edison International's and SCE's consolidated balance sheets. Edison International and SCE are currently evaluating the impact this standard will have on the results of operations and statements of cash flows. In June 2016, the FASB issued an accounting standards update to amend the guidance on the impairment of financial instruments. The new guidance adds an impairment model, known as the current expected credit loss model, which is based on expected losses rather than incurred losses. This guidance applies to most debt instruments, trade receivables, lease receivables, financial guarantee contracts, and loan commitments. This guidance is effective on January 1, 2020. Edison International and SCE are currently evaluating this new guidance. In August and November 2016, the FASB issued accounting standards updates to amend the guidance on the presentation and classification of certain cash receipts and cash payments in the statement of cash flows to reduce diversity in practice. This guidance addresses eight specific cash flow classification issues, including debt prepayment or extinguishment costs, proceeds from the settlement of corporate-owned life insurance, distributions received from equity method investments and restricted cash. This standard also clarifies the application of the predominance principle where cash receipts and payments have aspects of more than one class of cash flows. The new standard is effective on January 1, 2018. Edison International and SCE are currently evaluating this new guidance. In January 2017, the FASB issued an accounting standards update to simplify the accounting for goodwill impairment. This accounting standards update changes the procedural steps in applying the goodwill impairment test. A goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Edison International will apply this guidance to the goodwill impairment test beginning in 2020.

Summary of Significant Accoun31

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Cash Equivalents	The cash equivalents were as follows: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Money market funds $ 41 $ 37 $ 18 $ 8 Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Book balances reclassified to accounts payable $ 138 $ 162 $ 136 $ 158
Estimated Useful Lives (Authorized by the CPUC) and Weighted-Average Useful Lives of Property, Plant and Equipment	Estimated useful lives (authorized by the CPUC) and weighted-average useful lives of SCE's property, plant and equipment, are as follows: Estimated Useful Lives Weighted-Average Useful Lives Generation plant 10 years to 57 years 38 years Distribution plant 20 years to 60 years 43 years Transmission plant 40 years to 65 years 53 years General plant and other 5 years to 60 years 22 years
Reconciliation of the Changes in ARO Liability	The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde: December 31, (in millions) 2016 2015 Beginning balance $ 2,762 $ 2,819 Accretion 1 157 173 Revisions (165 ) (14 ) Liabilities settled (168 ) (216 ) Ending balance $ 2,586 $ 2,762 1 An ARO represents the present value of a future obligation. Accretion is an increase in the liability to account for the time value of money resulting from discounting.
Amortization of Deferred Financing Costs	Amortization of deferred financing costs charged to interest expense is as follows: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Amortization of deferred financing costs charged to interest expense $ 31 $ 33 $ 36 $ 27 $ 28 $ 32
EPS Attributable to Edison International Common Shareholders	EPS attributable to Edison International common shareholders was computed as follows: Years ended December 31, (in millions) 2016 2015 2014 Basic earnings per share – continuing operations: Income from continuing operations attributable to common shareholders $ 1,299 $ 985 $ 1,427 Participating securities dividends — (1 ) (1 ) Income from continuing operations available to common shareholders $ 1,299 $ 984 $ 1,426 Weighted average common shares outstanding 326 326 326 Basic earnings per share – continuing operations $ 3.99 $ 3.02 $ 4.38 Diluted earnings per share – continuing operations: Income from continuing operations attributable to common shareholders $ 1,299 $ 985 $ 1,427 Participating securities dividends — (1 ) (1 ) Income from continuing operations available to common shareholders $ 1,299 $ 984 $ 1,426 Income impact of assumed conversions 1 1 1 Income from continuing operations available to common shareholders and assumed conversions $ 1,300 $ 985 $ 1,427 Weighted average common shares outstanding 326 326 326 Incremental shares from assumed conversions 4 3 3 Adjusted weighted average shares – diluted 330 329 329 Diluted earnings per share – continuing operations $ 3.94 $ 2.99 $ 4.33

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant, and Equipment	SCE's property, plant and equipment included in the consolidated balance sheets is composed of the following: December 31, (in millions) 2016 2015 Distribution $ 22,332 $ 20,871 Transmission 12,549 11,592 Generation 3,376 3,138 General plant and other 4,633 4,543 Accumulated depreciation (9,000 ) (8,548 ) 33,890 31,596 Construction work in progress 2,790 3,218 Nuclear fuel, at amortized cost 126 131 Total utility property, plant and equipment $ 36,806 $ 34,945
Schedule of Jointly Owned Utility Projects	The following is SCE's investment in each asset as of December 31, 2016 : (in millions) Plant in Service Construction Work in Progress Accumulated Depreciation Nuclear Fuel (at amortized cost) Net Book Value Ownership Interest Transmission systems: Eldorado $ 235 $ 10 $ 21 $ — $ 224 59% Pacific Intertie 192 21 80 — 133 50% Generating station: Palo Verde (nuclear) 1,959 62 1,547 126 600 16% Total $ 2,386 $ 93 $ 1,648 $ 126 $ 957

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities Disclosure [Abstract]
Variable Interest Entity, Condensed Income Statement	The following table provides a summary of the trusts' income statements: Years ended December 31, (in millions) Trust I Trust II Trust III Trust IV Trust V 2016 Dividend income $ 27 $ 20 $ 16 $ 17 $ 13 Dividend distributions 27 20 16 17 13 2015 Dividend income $ 27 $ 20 $ 16 $ 6 * Dividend distributions 27 20 16 6 * 2014 Dividend income $ 27 $ 20 $ 13 * * Dividend distributions 27 20 13 * * * Not applicable

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 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: December 31, 2016 December 31, 2015 (in millions) Carrying Value 1 Fair Value Carrying Value 1 Fair Value Edison International $ 11,156 $ 12,368 $ 11,178 $ 12,252 SCE 10,333 11,539 10,539 11,592 1 Carrying value is net of debt issuance costs.
SCE
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: December 31, 2016 (in millions) Level 1 Level 2 Level 3 Netting and Collateral 1 Total Assets at fair value Derivative contracts $ — $ 6 $ 68 $ — $ 74 Other 33 — — — 33 Nuclear decommissioning trusts: Stocks 2 1,547 — — — 1,547 Fixed Income 3 865 1,751 — — 2,616 Short-term investments, primarily cash equivalents 36 170 — — 206 Subtotal of nuclear decommissioning trusts 4 2,448 1,921 — — 4,369 Total assets 2,481 1,927 68 — 4,476 Liabilities at fair value Derivative contracts — — 1,157 — 1,157 Total liabilities — — 1,157 — 1,157 Net assets (liabilities) $ 2,481 $ 1,927 $ (1,089 ) $ — $ 3,319 December 31, 2015 (in millions) Level 1 Level 2 Level 3 Netting and Collateral 1 Total Assets at fair value Derivative contracts $ — $ — $ 163 $ — $ 163 Other 28 — — — 28 Nuclear decommissioning trusts: Stocks 2 1,460 — — — 1,460 Fixed Income 3 947 1,776 — — 2,723 Short-term investments, primarily cash equivalents 91 81 — — 172 Subtotal of nuclear decommissioning trusts 4 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 70% of SCE's equity investments were located in the United States at both December 31, 2016 and 2015 . 3 Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $79 million and $111 million at December 31, 2016 and 2015 , respectively. 4 Excludes net payables of $127 million and $24 million at December 31, 2016 and 2015 , which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.
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: December 31, (in millions) 2016 2015 Fair value of net liabilities at beginning of period $ (1,148 ) $ (902 ) Total realized/unrealized gains (losses): Included in regulatory assets and liabilities 1 59 (246 ) Fair value of net liabilities at end of period $ (1,089 ) $ (1,148 ) Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period $ (70 ) $ (311 ) 1 Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities.
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 December 31, 2016 $ 67 $ — Market simulation model and auction prices Load forecast 3,708 MW - 22,840 MW Power prices 1 $3.65 - $99.58 Gas prices 2 $2.51 - $4.87 December 31, 2015 152 — Market simulation model and auction prices Load forecast 6,289 MW - 24,349 MW Power prices 1 $0 - $110.44 Gas prices 2 $1.98 - $5.72 Tolling December 31, 2016 — 1,154 Option model Volatility of gas prices 15% - 48% (20%) Volatility of power prices 29% - 71% (40%) Power prices $23.40 - $51.24 ($34.70) December 31, 2015 10 1,297 Option model Volatility of gas prices 15% - 58% (20%) Volatility of power prices 26% - 38% (30%) Power prices $24.15 - $46.93 ($34.80) 1 Prices are in dollars per megawatt-hour. 2 Prices are in dollars per million British thermal units.

Debt and Credit Agreements (Tab

Debt and Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-term Debt	The following table summarizes long-term debt (rates and terms are as of December 31, 2016 ) of Edison International and SCE: December 31, (in millions) 2016 2015 Edison International Parent and Other: Debentures and notes: 2017 – 2023 (2.95% to 3.75%) $ 800 $ 614 Other long-term debt 32 31 Current portion of long-term debt (402 ) (216 ) Unamortized debt discount and issuance costs, net (9 ) (6 ) Total Edison International Parent and Other 421 423 SCE: First and refunding mortgage bonds: 2017 – 2045 (1.125% to 6.05%) 9,357 9,436 Pollution-control bonds: 2028 – 2035 (1.375% to 5.0%) 1 774 909 Debentures and notes: 2029 – 2053 (5.06% to 6.65%) 307 307 Current portion of long-term debt (579 ) (79 ) Unamortized debt discount and issuance costs, net (105 ) (113 ) Total SCE 9,754 10,460 Total Edison International $ 10,175 $ 10,883 1 Excludes outstanding bonds that have not been retired and may be remarketed to investors in the future. These bonds have variable rates and are due in 2031 and 2033 at December 31, 2016 and 2031 at December 31, 2015.
Long-term Debt Maturities	Edison International and SCE long-term debt maturities over the next five years are the following: (in millions) Edison International SCE 2017 $ 981 $ 579 2018 482 479 2019 82 79 2020 80 79 2021 580 579
Summary for Status of Credit Facilities	The following table summarizes the status of the credit facilities at December 31, 2016 : (in millions) Edison International Parent SCE Commitment $ 1,250 $ 2,750 Outstanding borrowings (538 ) (769 ) Outstanding letters of credit — (91 ) Amount available $ 712 $ 1,890

Derivative Instruments (Tables)

Derivative Instruments (Tables) - SCE	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Derivative Liabilities in Statement of Financial Position, Fair Value	The following table summarizes the gross and net fair values of SCE's commodity derivative instruments: December 31, 2016 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 74 $ 1 $ 75 $ 217 $ 941 $ 1,158 $ 1,083 Gross amounts offset in consolidated balance sheets (1 ) — (1 ) (1 ) — (1 ) — Cash collateral posted 1 — — — — — — — Net amounts presented in the consolidated balance sheets $ 73 $ 1 $ 74 $ 216 $ 941 $ 1,157 $ 1,083 December 31, 2015 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 81 $ 84 $ 165 $ 235 $ 1,100 $ 1,335 $ 1,170 Gross amounts offset in consolidated balance sheets (2 ) — (2 ) (2 ) — (2 ) — Cash collateral posted 1 — — — (15 ) — (15 ) (15 ) Net amounts presented in the consolidated balance sheets $ 79 $ 84 $ 163 $ 218 $ 1,100 $ 1,318 $ 1,155 1 In addition, at December 31, 2016 , SCE received $2 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015 , SCE had posted $31 million of cash collateral that is not offset against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets.
Schedule of Derivative Assets in Statement of Financial Position, Fair Value	The following table summarizes the gross and net fair values of SCE's commodity derivative instruments: December 31, 2016 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 74 $ 1 $ 75 $ 217 $ 941 $ 1,158 $ 1,083 Gross amounts offset in consolidated balance sheets (1 ) — (1 ) (1 ) — (1 ) — Cash collateral posted 1 — — — — — — — Net amounts presented in the consolidated balance sheets $ 73 $ 1 $ 74 $ 216 $ 941 $ 1,157 $ 1,083 December 31, 2015 Derivative Assets Derivative Liabilities Net Liability (in millions) Short-Term Long-Term Subtotal Short-Term Long-Term Subtotal Commodity derivative contracts Gross amounts recognized $ 81 $ 84 $ 165 $ 235 $ 1,100 $ 1,335 $ 1,170 Gross amounts offset in consolidated balance sheets (2 ) — (2 ) (2 ) — (2 ) — Cash collateral posted 1 — — — (15 ) — (15 ) (15 ) Net amounts presented in the consolidated balance sheets $ 79 $ 84 $ 163 $ 218 $ 1,100 $ 1,318 $ 1,155 1 In addition, at December 31, 2016 , SCE received $2 million of collateral that is not offset against derivative assets and is reflected in "Other current liabilities" on the consolidated balance sheets. At December 31, 2015 , SCE had posted $31 million of cash collateral that is not offset against derivative liabilities and is reflected in "Other current assets" on the consolidated balance sheets.
Derivative Instruments, Gain (Loss)	The following table summarizes the components of SCE's economic hedging activity: Years ended December 31, (in millions) 2016 2015 2014 Realized losses $ (59 ) $ (148 ) $ (57 ) Unrealized gains (losses) 84 (182 ) (147 )
Notional Volumes of Derivative Instruments	The following table summarizes the notional volumes of derivatives used for SCE hedging activities: Economic Hedges Unit of December 31, Commodity Measure 2016 2015 Electricity options, swaps and forwards GWh 1,816 6,221 Natural gas options, swaps and forwards Bcf 36 32 Congestion revenue rights GWh 93,319 109,740 Tolling arrangements GWh 61,093 70,663

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Sources of Income (Loss) Before Income Taxes	Edison International's sources of income (loss) before income taxes are: Years ended December 31, (in millions) 2016 2015 2014 Income from continuing operations before income taxes $ 1,590 $ 1,568 $ 1,979 Income (loss) from discontinued operations before income taxes 1 15 (525 ) Income before income tax $ 1,591 $ 1,583 $ 1,454
Components of Income Tax Expense (Benefit) by Location of Taxing Jurisdiction	The components of income tax expense (benefit) by location of taxing jurisdiction are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Current: Federal $ (46 ) $ 18 $ (99 ) $ 75 $ 72 $ (89 ) State 33 19 20 93 127 101 (13 ) 37 (79 ) 168 199 12 Deferred: Federal 176 340 454 112 298 476 State 14 109 68 (24 ) 10 (14 ) 190 449 522 88 308 462 Total continuing operations 177 486 443 256 507 474 Discontinued operations 1 (11 ) (21 ) (710 ) — — — Total $ 166 $ 465 $ (267 ) $ 256 $ 507 $ 474 1 See Note 15 for a discussion of discontinued operations related to EME.
Components of Net Accumulated Deferred Income Tax Liability	The components of net accumulated deferred income tax liability are: Edison International SCE December 31, (in millions) 2016 2015 2016 2015 Deferred tax assets: Property and software related $ 549 $ 675 $ 548 $ 675 Nuclear decommissioning trust assets in excess of nuclear ARO liability 348 360 348 360 Loss and credit carryforwards 1,418 1,388 — — Regulatory balancing accounts 15 21 15 21 Pension and PBOPs 300 337 93 154 Other 419 499 408 411 Sub-total 3,049 3,280 1,412 1,621 Less valuation allowance 24 32 — — Total 3,025 3,248 1,412 1,621 Deferred tax liabilities: Property-related 10,330 9,606 10,330 9,600 Capitalized software costs 237 207 237 207 Regulatory balancing accounts 134 202 134 202 Nuclear decommissioning trust assets 348 360 348 360 PBOPs 13 71 13 71 Other 202 189 148 161 Total 11,264 10,635 11,210 10,601 Accumulated deferred income tax liability, net 1 $ 8,239 $ 7,387 $ 9,798 $ 8,980 1 Included in deferred income taxes and credits.
Summary of Tax Credit Carryforwards	The amounts of net operating loss and tax credit carryforwards (after-tax) are as follows: Edison International SCE December 31, 2016 (in millions) Loss Carryforwards Credit Carryforwards Loss Carryforwards Credit Carryforwards Expire between 2017 to 2035 $ 1,095 $ 430 $ 20 $ 25 No expiration date — 69 — 37 Total 1 $ 1,095 $ 499 $ 20 $ 62 1 Deferred tax assets for net operating loss and tax credit carryforwards are reduced by unrecognized tax benefits of $176 million and $82 million for Edison International and SCE, respectively.
Reconciliation of Income Tax Expense	The table below provides a reconciliation of income tax expense computed at the federal statutory income tax rate to the income tax provision: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Income from continuing operations before income taxes $ 1,590 $ 1,568 $ 1,979 $ 1,755 $ 1,618 $ 2,039 Provision for income tax at federal statutory rate of 35% 556 549 693 614 566 714 Increase in income tax from: Items presented with related state income tax, net: Regulatory asset write-off 1 — 382 — — 382 — State tax, net of federal benefit 29 5 56 43 34 55 Property-related 2 (362 ) (341 ) (252 ) (362 ) (341 ) (252 ) Change related to uncertain tax positions (4 ) (67 ) 5 (8 ) (94 ) 12 San Onofre OII settlement — — (23 ) — — (23 ) Share-based compensation 3 (28 ) — — (13 ) — — Other (14 ) (42 ) (36 ) (18 ) (40 ) (32 ) Total income tax expense from continuing operations $ 177 $ 486 $ 443 $ 256 $ 507 $ 474 Effective tax rate 11.1 % 31.0 % 22.4 % 14.6 % 31.3 % 23.2 % 1 Includes federal and state. 2 Includes incremental repair benefits. See discussion of repair deductions below. 3 Includes state taxes of $(4) million and $(1) million for Edison International and SCE, respectively. Refer to Note 1 for further information.
Reconciliation of Unrecognized Tax Benefits	The following table provides a reconciliation of unrecognized tax benefits for continuing and discontinued operations: Edison International SCE December 31, (in millions) 2016 2015 2014 2016 2015 2014 Balance at January 1, $ 529 $ 576 $ 815 $ 353 $ 441 $ 532 Tax positions taken during the current year: Increases 36 54 65 36 48 57 Tax positions taken during a prior year: Increases 2 66 1 — 23 — Decreases 1 (96 ) (165 ) (143 ) (18 ) (159 ) (93 ) Decreases for settlements during the period 2 — (2 ) (162 ) — — (55 ) Balance at December 31, $ 471 $ 529 $ 576 $ 371 $ 353 $ 441 1 Decreases in prior year tax positions for 2016 relate to state tax receivables on various claims. Due to the tax risks associated with these claims, the tax benefits were fully reserved at the time the asset was recorded. During 2016, the Company has determined that it will not recognize these assets so the tax benefit and related tax reserve were written off. Decreases in tax positions for 2015 relate primarily to re-measurement of uncertain tax positions in connection with receipt of the IRS Revenue Agent Report in June 2015. See discussions in Tax Disputes below. 2 In the fourth quarter of 2014, Edison International has settled all open tax positions with the IRS for taxable years 2003 through 2006.
Schedule of Interest and Penalties Related to Income Tax Liabilities	The total amount of accrued interest and penalties related to income tax liabilities for continuing and discontinued operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Accrued interest and penalties $ 128 $ 122 $ 41 $ 40 The net after-tax interest and penalties recognized in income tax expense for continuing and discontinued operations are: Edison International SCE December 31, (in millions) 2016 2015 2014 2016 2015 2014 Net after-tax interest and penalties tax benefit $ 6 $ 9 $ 41 $ 2 $ 14 $ 16

Compensation and Benefit Plans

Compensation and Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2016
Pension and Other Postretirement Benefits
Employee Savings Plan Employer Contributions	The following employer contributions were made for continuing operations: Edison International SCE (in millions) Years ended December 31, 2016 $ 69 $ 68 2015 73 72 2014 71 70
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs	The following table summarizes total expense and tax benefits (expense) associated with stock based compensation: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Stock-based compensation expense 1 : Stock options $ 14 $ 14 $ 16 $ 7 $ 8 $ 8 Performance shares 13 7 16 6 4 8 Restricted stock units 6 7 7 3 4 4 Other 1 1 1 — — — Total stock-based compensation expense $ 34 $ 29 $ 40 $ 16 $ 16 $ 20 Income tax benefits related to stock compensation expense $ 41 $ 12 $ 16 $ 20 $ 7 $ 8 Excess tax benefits 2 — 15 15 — 23 20 1 Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income. 2 Reflected in "Settlements of stock-based compensation, net" in the financing section of Edison International's and SCE's consolidated statements of cash flows, "Common stock" in Edison International's consolidated balance sheets and "Additional paid-in capital" in SCE's consolidated balance sheets. Edison International and SCE adopted the new accounting guidance for shared-based payments, see Note 1 for further information.
Black-Sholes Option-Pricing Model Assumptions	The Black-Scholes option-pricing model requires various assumptions noted in the following table: Years ended December 31, 2016 2015 2014 Expected terms (in years) 5.9 5.9 6.0 Risk-free interest rate 1.2% – 2.2% 1.6% – 2.1% 1.8% – 2.1% Expected dividend yield 2.5% – 3.0% 2.6% – 3.2% 2.4% – 2.7% Weighted-average expected dividend yield 2.9% 2.6% 2.7% Expected volatility 17.2% – 17.5% 16.4% – 17.0% 17.8% – 19.1% Weighted-average volatility 17.4% 16.5% 18.9%
Summary of Stock Options Activity	The following is a summary of the status of Edison International's stock options: Weighted-Average Stock options Exercise Price Remaining Contractual Term (Years) Aggregate Intrinsic Value (in millions) Edison International: Outstanding at December 31, 2015 12,866,597 $ 45.93 Granted 2,120,009 67.41 Expired — — Forfeited (274,166 ) 64.02 Exercised (3,167,939 ) 42.93 Outstanding at December 31, 2016 11,544,501 50.26 6.02 Vested and expected to vest at December 31, 2016 11,437,110 50.12 5.99 $ 250 Exercisable at December 31, 2016 7,685,341 $ 43.99 4.93 $ 215 SCE: Outstanding at December 31, 2015 5,840,057 $ 47.77 Granted 959,478 67.36 Expired — — Forfeited (120,842 ) 61.96 Exercised (1,705,053 ) 44.59 Transfers, net (246,224 ) 59.29 Outstanding at December 31, 2016 4,727,416 51.81 6.24 Vested and expected to vest at December 31, 2016 4,667,784 51.63 6.21 $ 95 Exercisable at December 31, 2016 2,782,770 $ 44.04 4.84 $ 78
Schedule of Unrecognized Compensation Expense	At December 31, 2016 , total unrecognized compensation cost related to stock options and the weighted-average period the cost is expected to be recognized are as follows: (in millions) Edison International SCE Unrecognized compensation cost, net of expected forfeitures $ 13 $ 8 Weighted-average period (in years) 2.3 2.3
Supplemental Data on Stock-based Compensation	Supplemental Data on Stock Options Edison International SCE Years ended December 31, (in millions, except per award amounts) 2016 2015 2014 2016 2015 2014 Stock options: Weighted average grant date fair value per option granted $ 7.38 $ 7.54 $ 7.26 $ 7.50 $ 7.53 $ 7.34 Fair value of options vested 11 20 17 5 11 9 Cash used to purchase shares to settle options 220 170 300 118 69 181 Cash from participants to exercise stock options 136 113 205 77 45 125 Value of options exercised 84 57 95 41 24 56 Tax benefits from options exercised 34 23 39 17 10 23
Summary of Nonvested Share Activity	The following is a summary of the status of Edison International's nonvested performance shares: Equity Awards Liability Awards Shares Weighted-Average Grant Date Fair Value Shares Weighted-Average Fair Value Edison International: Nonvested at December 31, 2015 57,779 $ 61.18 165,629 $ 68.44 Granted — — 111,754 Forfeited (1,258 ) 60.83 (13,502 ) Vested 1 (56,521 ) 61.18 (56,384 ) Nonvested at December 31, 2016 — — 207,497 84.30 SCE: Nonvested at December 31, 2015 32,463 $ 62.01 90,393 $ 68.64 Granted — — 50,599 Forfeited (1,012 ) 49.73 (5,751 ) Vested 1 (29,080 ) 50.75 (28,963 ) Affiliate transfers, net (2,371 ) 72.10 (9,611 ) Nonvested at December 31, 2016 — — 96,667 84.25 1 Relates to performance shares that will be paid in 2017 as performance targets were met at December 31, 2016 .
Summary of Nonvested Restricted Stock Units Activity	The following is a summary of the status of Edison International's nonvested restricted stock units: Edison International SCE Restricted Stock Units Weighted-Average Grant Date Fair Value Restricted Stock Units Weighted-Average Grant Date Fair Value Nonvested at December 31, 2015 248,143 $ 57.89 134,375 $ 58.13 Granted 123,266 67.42 55,800 67.37 Forfeited (16,435 ) 63.73 (7,580 ) 61.45 Vested (9,579 ) 52.01 (8,032 ) 56.53 Affiliate transfers, net — — (13,775 ) 62.09 Nonvested at December 31, 2016 345,395 61.05 160,788 60.80
Accrued Severance Liability Workforce Reduction	The following table provides a summary of changes in the accrued severance liability associated with these reductions: (in millions) Balance at January 1, 2016 $ 22 Additions 21 Payments (40 ) Balance at December 31, 2016 $ 3
Pension Plans
Pension and Other Postretirement Benefits
Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan	Information on pension plan assets and benefit obligations for continuing and discontinued operations is shown below. Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Change in projected benefit obligation Projected benefit obligation at beginning of year $ 4,374 $ 4,517 $ 3,878 $ 3,999 Service cost 139 142 132 133 Interest cost 171 170 150 150 Actuarial gain (125 ) (149 ) (140 ) (143 ) Benefits paid (275 ) (305 ) (229 ) (261 ) Other — (1 ) — — Projected benefit obligation at end of year $ 4,284 $ 4,374 $ 3,791 $ 3,878 Change in plan assets Fair value of plan assets at beginning of year $ 3,298 $ 3,454 $ 3,080 $ 3,217 Actual return on plan assets 262 30 239 27 Employer contributions 103 119 82 97 Benefits paid (275 ) (305 ) (229 ) (261 ) Fair value of plan assets at end of year $ 3,388 $ 3,298 $ 3,172 $ 3,080 Funded status at end of year $ (896 ) $ (1,076 ) $ (619 ) $ (798 ) Amounts recognized in the consolidated balance sheets consist of 1 : Long-term assets $ 2 $ — $ — $ — Current liabilities (50 ) (27 ) (4 ) (4 ) Long-term liabilities (848 ) (1,049 ) (615 ) (794 ) $ (896 ) $ (1,076 ) $ (619 ) $ (798 ) Amounts recognized in accumulated other comprehensive loss consist of: Prior service cost $ (1 ) $ — $ — $ — Net loss 1 93 96 24 27 $ 92 $ 96 $ 24 $ 27 Amounts recognized as a regulatory asset $ 574 $ 675 $ 574 $ 675 Total not yet recognized as expense $ 666 $ 771 $ 598 $ 702 Accumulated benefit obligation at end of year $ 4,138 $ 4,200 $ 3,683 $ 3,744 Pension plans with an accumulated benefit obligation in excess of plan assets: Projected benefit obligation $ 4,284 $ 4,374 $ 3,791 $ 3,878 Accumulated benefit obligation 4,138 4,200 3,683 3,744 Fair value of plan assets 3,388 3,298 3,172 3,080 Weighted-average assumptions used to determine obligations at end of year: Discount rate 3.94 % 4.18 % 3.94 % 4.18 % Rate of compensation increase 4.00 % 4.00 % 4.00 % 4.00 % 1 The SCE liability excludes a long-term payable due to Edison International Parent of $124 million and $123 million at December 31, 2016 and 2015 , respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent. SCE's accumulated other comprehensive loss of $24 million and $27 million at December 31, 2016 and 2015 , respectively, excludes net loss of $ 20 million and $18 million related to these benefits.
Expense Components for Plans	Pension expense components for continuing operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Service cost $ 139 $ 142 $ 133 $ 136 $ 139 $ 128 Interest cost 172 170 181 156 155 164 Expected return on plan assets (220 ) (233 ) (229 ) (205 ) (217 ) (213 ) Settlement costs 1 — — 45 — — 42 Curtailment gain — — (4 ) — — — Amortization of prior service cost 4 5 5 4 5 5 Amortization of net loss 2 27 40 12 23 35 7 Expense under accounting standards 122 124 143 114 117 133 Regulatory adjustment (deferred) (21 ) (6 ) 8 (21 ) (6 ) 8 Total expense recognized $ 101 $ 118 $ 151 $ 93 $ 111 $ 141 1 Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International was zero for the both the years ended December 31, 2016 and 2015 and $3 million for the year ended December 31, 2014 . 2 Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $10 million and $6 million , respectively, for the year ended December 31, 2016 . The amount reclassified for Edison International and SCE was $14 million and $8 million , respectively, for the year ended December 31, 2015 . The amount reclassified for Edison International and SCE was $9 million and $4 million , respectively, for the year ended December 31, 2014
Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income	Other changes in pension plan assets and benefit obligations recognized in other comprehensive loss for continuing operations: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Net loss (gain) $ 6 $ 7 $ 85 $ 4 $ (9 ) $ 37 Amortization of net loss and other (10 ) (15 ) (13 ) (6 ) (9 ) (4 ) Total recognized in other comprehensive loss $ (4 ) $ (8 ) $ 72 $ (2 ) $ (18 ) $ 33 Total recognized in expense and other comprehensive loss $ 97 $ 110 $ 223 $ 91 $ 93 $ 174
Schedule of Amounts in Accumulated Other Comprehensive Loss to be Recognized	The estimated pension amounts that will be amortized to expense in 2017 for continuing operations are as follows: (in millions) Edison International SCE Unrecognized net loss to be amortized 1 $ 19 $ 15 Unrecognized prior service cost to be amortized 3 3 1 The amount of net loss expected to be reclassified from other comprehensive loss for Edison International's continuing operations and SCE is $10 million and $6 million , respectively.
Schedule of Assumptions Used	Edison International and SCE used the following weighted-average assumptions to determine pension expense for continuing operations: Years ended December 31, 2016 2015 2014 Discount rate 4.18 % 3.85 % 4.50 % Rate of compensation increase 4.00 % 4.00 % 4.00 % Expected long-term return on plan assets 7.00 % 7.00 % 7.00 %
Schedule of Expected Benefit Payments	The following benefit payments, which reflect expected future service, are expected to be paid: Edison International SCE (in millions) Years ended December 31, 2017 $ 346 $ 271 2018 332 298 2019 344 300 2020 341 304 2021 341 304 2022 – 2026 1,566 1,396
Postretirement Benefits Other than Pension Plan Assets by Hierarchy Levels	The following table sets forth the Master Trust investments for Edison International and SCE that were accounted for at fair value as of December 31, 2016 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 217 $ 309 $ — $ — $ 526 Corporate stocks 3 720 15 — — 735 Corporate bonds 4 — 725 — — 725 Common/collective funds 5 — — — 692 692 Partnerships/joint ventures 6 — — — 333 333 Other investment entities 7 — — — 253 253 Registered investment companies 8 124 — — 6 130 Interest-bearing cash 42 — — — 42 Other — 112 — — 112 Total $ 1,103 $ 1,161 $ — $ 1,284 $ 3,548 Receivables and payables, net (160 ) Net plan assets available for benefits $ 3,388 SCE's share of net plan assets $ 3,172 The following table sets forth the Master Trust investments that were accounted for at fair value as of December 31, 2015 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 127 $ 298 $ — $ — $ 425 Corporate stocks 3 720 16 — — 736 Corporate bonds 4 — 755 — — 755 Common/collective funds 5 — — — 640 640 Partnerships/joint ventures 6 — — — 325 325 Other investment entities 7 — — — 263 263 Registered investment companies 8 117 — — 4 121 Interest-bearing cash 6 — — — 6 Other 1 96 — — 97 Total $ 971 $ 1,165 $ — $ 1,232 $ 3,368 Receivables and payables, net (70 ) Net plan assets available for benefits $ 3,298 SCE's share of net plan assets $ 3,080 1 These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits. 2 Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal National Mortgage Association and the Federal Home Loan Mortgage Corporation. 3 Corporate stocks are diversified. At December 31, 2016 and 2015 , respectively, performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 62% ) and ( 59% ) and Morgan Stanley Capital International (MSCI) index ( 38% ) and ( 41% ). 4 Corporate bonds are diversified. At December 31, 2016 and 2015 , respectively, this category includes $76 million and $123 million for collateralized mortgage obligations and other asset backed securities of which $27 million and $25 million are below investment grade. 5 At December 31, 2016 and 2015 , respectively, the common/collective assets were invested in equity index funds that seek to track performance of the Standard and Poor's (S&P 500) Index ( 45% and 46% ) and Russell 1000 indexes ( 15% and 14% ). At December 31, 2016 and 2015, 15% and 16% of the assets in this category are in index funds which seek to track performance in the MSCI All Country World Index exUS and MSCI Europe, Australasia and Far East (EAFE) Index, respectively. A non-index U.S. equity fund representing 23% and 22% of this category for 2016 and 2015 , respectively, is actively managed. 6 At December 31, 2016 and 2015 , respectively, 55% and 51% are invested in private equity funds with investment strategies that include branded consumer products, clean technology and California geographic focus companies, 22% and 20% are invested in publicly traded fixed income securities, 18% and 14% are invested in a broad range of financial assets in all global markets and 4% and 15% of the remaining partnerships are invested in asset backed securities, including distressed mortgages and commercial and residential loans and debt and equity of banks. 7 Other investment entities were primarily invested in (1) emerging market equity securities, (2) a hedge fund that invests through liquid instruments in a global diversified portfolio of equity, fixed income, interest rate, foreign currency and commodities markets, and (3) domestic mortgage backed securities. 8 Level 1 of registered investment companies primarily consisted of a global equity mutual fund which seeks to outperform the MSCI World Total Return Index. The funds classified as NAV primarily consisted of a fixed income securities fund.
Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan	Information on PBOP Plan assets and benefit obligations is shown below: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Change in benefit obligation Benefit obligation at beginning of year $ 2,350 $ 2,784 $ 2,341 $ 2,775 Service cost 35 46 34 46 Interest cost 97 102 97 102 Special termination benefits 2 (2 ) 2 (2 ) Plan Amendments (6 ) — (6 ) — Actuarial gain (110 ) (500 ) (110 ) (500 ) Plan participants' contributions 19 20 19 20 Benefits paid (111 ) (100 ) (111 ) (100 ) Benefit obligation at end of year $ 2,276 $ 2,350 $ 2,266 $ 2,341 Change in plan assets Fair value of plan assets at beginning of year $ 2,036 $ 2,086 $ 2,036 $ 2,086 Actual return on assets 137 6 137 6 Employer contributions 21 24 21 24 Plan participants' contributions 19 20 19 20 Benefits paid (111 ) (100 ) (111 ) (100 ) Fair value of plan assets at end of year $ 2,102 $ 2,036 $ 2,102 $ 2,036 Funded status at end of year $ (174 ) $ (314 ) $ (164 ) $ (305 ) Amounts recognized in the consolidated balance sheets consist of: Current liabilities $ (14 ) $ (15 ) $ (13 ) $ (15 ) Long-term liabilities (160 ) (299 ) (151 ) (290 ) $ (174 ) $ (314 ) $ (164 ) $ (305 ) Amounts recognized in accumulated other comprehensive loss consist of: Net loss $ 4 $ 4 $ — $ — Amounts recognized as a regulatory asset $ 136 $ 174 $ 136 $ 174 Total not yet recognized as expense $ 140 $ 178 $ 136 $ 174 Weighted-average assumptions used to determine obligations at end of year: Discount rate 4.29 % 4.55 % 4.29 % 4.55 % Assumed health care cost trend rates: Rate assumed for following year 7.00 % 7.50 % 7.00 % 7.50 % Ultimate rate 5.00 % 5.00 % 5.00 % 5.00 % Year ultimate rate reached 2022 2022 2022 2022
Expense Components for Plans	PBOP expense components for continuing operations are: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Service cost $ 35 $ 46 $ 40 $ 34 $ 46 $ 40 Interest cost 97 102 117 97 102 117 Expected return on plan assets (112 ) (116 ) (108 ) (112 ) (116 ) (108 ) Special termination benefits 1 2 1 3 2 1 3 Amortization of prior service credit (2 ) (12 ) (36 ) (2 ) (12 ) (35 ) Amortization of net loss — 3 6 — 2 5 Total expense $ 20 $ 24 $ 22 $ 19 $ 23 $ 22 1 Due to the reduction in workforce, SCE has incurred costs for extended retiree health care coverage.
Schedule of Amounts in Accumulated Other Comprehensive Loss to be Recognized	The estimated PBOP amounts that will be amortized to expense in 2017 for continuing operations are as follows: Edison International SCE Unrecognized prior service credit to be amortized $ (2 ) $ (2 )
Schedule of Assumptions Used	Edison International and SCE used the following weighted-average assumptions to determine PBOP expense for continuing operations: Years ended December 31, 2016 2015 2014 Discount rate 4.55 % 4.16 % 5.00 % Expected long-term return on plan assets 5.60 % 5.50 % 5.50 % Assumed health care cost trend rates: Current year 7.50 % 7.75 % 7.75 % Ultimate rate 5.00 % 5.00 % 5.00 % Year ultimate rate reached 2022 2021 2020
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rate	A one-percentage-point change in assumed health care cost trend rate would have the following effects on continuing operations: Edison International SCE (in millions) One-Percentage-Point Increase One-Percentage-Point Decrease One-Percentage-Point Increase One-Percentage-Point Decrease Effect on accumulated benefit obligation as of December 31, 2016 $ 244 $ (200 ) $ 243 $ (199 ) Effect on annual aggregate service and interest costs 11 (9 ) 11 (9 )
Schedule of Expected Benefit Payments	The following benefit payments are expected to be paid: Edison International SCE (in millions) Years ended December 31, 2017 $ 98 $ 98 2018 102 102 2019 105 105 2020 109 109 2021 113 112 2022 – 2026 612 609
Postretirement Benefits Other than Pension Plan Assets by Hierarchy Levels	The following table sets forth the VEBA Trust assets for Edison International and SCE that were accounted for at fair value as of December 31, 2016 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 222 $ 59 $ — $ — $ 281 Corporate stocks 3 230 — — — 230 Corporate notes and bonds 4 — 877 — — 877 Common/collective funds 5 — — — 462 462 Partnerships 6 — — — 79 79 Registered investment companies 7 48 — — 1 49 Interest bearing cash 48 — — — 48 Other 8 4 103 — — 107 Total $ 552 $ 1,039 $ — $ 542 $ 2,133 Receivables and payables, net (31 ) Combined net plan assets available for benefits $ 2,102 The following table sets forth the VEBA Trust assets for SCE that were accounted for at fair value as of December 31, 2015 by asset class and level within the fair value hierarchy: (in millions) Level 1 Level 2 Level 3 NAV 1 Total U.S. government and agency securities 2 $ 200 $ 42 $ — $ — $ 242 Corporate stocks 3 222 — — — 222 Corporate notes and bonds 4 — 867 — — 867 Common/collective funds 5 — — — 424 424 Partnerships 6 — — — 93 93 Registered investment companies 7 60 — — 3 63 Interest bearing cash 31 — — — 31 Other 8 5 113 — — 118 Total $ 518 $ 1,022 $ — $ 520 $ 2,060 Receivables and payables, net (24 ) Combined net plan assets available for benefits $ 2,036 1 These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits. 2 Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal Home Loan Mortgage Corporation and the Federal National Mortgage Association. 3 Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes ( 47% ) and the MSCI All Country World Index ( 53% ) for both 2016 and 2015 . 4 Corporate notes and bonds are diversified and include approximately $47 million and $27 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2016 and 2015 , respectively. 5 At December 31, 2016 and 2015 , respectively, 39% and 38% of the common/collective assets are invested in a large cap index fund which seeks to track performance of the Russell 1000 index. 39% and 41% of the remaining assets in this category are in index funds which seek to track performance in the MSCI All Country World Index Investable Market Index and MSCI Europe, Australasia and Far East (EAFE) Index. 18% and 17% in a non-index U.S. equity fund which is actively managed. 6 At December 31, 2016 and 2015 , respectively, 59% and 56% of the partnerships are invested in private equity and venture capital funds. Investment strategies for these funds include branded consumer products, clean and information technology and healthcare. 31% and 21% are invested in a broad range of financial assets in all global markets. 9% and 23% of the remaining partnerships category is invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks. 7 Level 1 registered investment companies consist of a money market fund. 8 Other includes $76 million and $97 million of municipal securities at December 31, 2016 and 2015 , respectively.

Investments (Tables)

Investments (Tables)	12 Months Ended
	Dec. 31, 2016
Regulated Entity, Other Assets, Noncurrent [Abstract]
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 Date Amortized Cost Fair Value December 31, (in millions) 2016 2015 2016 2015 Stocks — $ 319 $ 304 $ 1,547 $ 1,460 Municipal bonds 2054 659 691 766 840 U.S. government and agency securities 2055 1,131 1,070 1,191 1,128 Corporate bonds 2057 600 708 659 755 Short-term investments and receivables/payables 1 One-year 75 144 79 148 Total $ 2,784 $ 2,917 $ 4,242 $ 4,331 1 Short-term investments include $114 million and $81 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by January 4, 2017 and January 5, 2016 as of December 31, 2016 and 2015 , respectively.
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: Years ended December 31, (in millions) 2016 2015 2014 Balance at beginning of period $ 4,331 $ 4,799 $ 4,494 Gross realized gains 92 326 197 Gross realized losses (19 ) (26 ) (5 ) Unrealized gains (losses) 44 (364 ) 75 Other-than-temporary impairments (36 ) (29 ) (14 ) Interest, dividends and other 116 115 118 Contributions — 54 5 Income taxes (58 ) (64 ) (62 ) Decommissioning disbursements (224 ) (471 ) (4 ) Administrative expenses and other (4 ) (9 ) (5 ) Balance at end of period $ 4,242 $ 4,331 $ 4,799

Regulatory Assets and Liabili40

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets Included on the Consolidated Balance Sheets	SCE's regulatory assets included on the consolidated balance sheets are: December 31, (in millions) 2016 2015 Current: Regulatory balancing accounts $ 135 $ 382 Energy derivatives 150 159 Unamortized investments, net 49 — Other 16 19 Total current 350 560 Long-term: Deferred income taxes, net 4,478 3,757 Pensions and other postretirement benefits 710 849 Energy derivatives 947 1,027 Unamortized investments, net 80 182 San Onofre 857 1,043 Unamortized loss on reacquired debt 184 201 Regulatory balancing accounts 66 36 Environmental remediation 126 129 Other 7 288 Total long-term 7,455 7,512 Total regulatory assets $ 7,805 $ 8,072
Regulatory Liabilities Included on the Consolidated Balance Sheets	SCE's regulatory liabilities included on the consolidated balance sheets are: December 31, (in millions) 2016 2015 Current: Regulatory balancing accounts $ 736 $ 1,106 Other 20 22 Total current 756 1,128 Long-term: Costs of removal 2,847 2,781 Recoveries in excess of ARO liabilities 1,639 1,502 Regulatory balancing accounts 1,180 1,314 Other 60 79 Total long-term 5,726 5,676 Total regulatory liabilities $ 6,482 $ 6,804
Schedule of Regulatory Balancing Accounts	The following table summarizes the significant components of regulatory balancing accounts included in the above tables of regulatory assets and liabilities: December 31, (in millions) 2016 2015 Asset (liability) Energy resource recovery account $ (20 ) $ (439 ) New system generation balancing account (6 ) (171 ) Public purpose programs and energy efficiency programs (992 ) (683 ) Base revenue requirement balancing account (426 ) (319 ) Tax accounting memorandum account and pole loading (142 ) (248 ) DOE litigation memorandum account 1 (122 ) — Greenhouse gas auction revenue 31 (75 ) FERC balancing accounts (69 ) 74 Other 31 (141 ) Liability $ (1,715 ) $ (2,002 ) 1 Represents proceeds from the Department of Energy ("DOE") resulting from its failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. Damages recovered are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs. See Note 11 for further discussion.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule Of Commitments And Contingencies [Line Items]
Summary of Power Purchase Agreements Treated as Operating and Capital Leases	The amount of this discount is shown in the table below as the amount representing interest. (in millions) Operating Leases Capital Leases 2017 $ 341 $ 1 2018 237 1 2019 161 1 2020 146 2 2021 142 2 Thereafter 1,355 9 Total future commitments $ 2,382 $ 16 Amount representing executory costs (7 ) Amount representing interest (2 ) Net commitments $ 7
Summary of Estimated Minimum Future Commitments for Other Operating Leases	The following summarizes the estimated minimum future commitments for SCE's non-cancelable other operating leases (excluding SCE's power purchase agreements discussed above): (in millions) Operating Leases – Other 2017 $ 52 2018 46 2019 37 2020 28 2021 22 Thereafter 258 Total future commitments $ 443
SCE
Schedule Of Commitments And Contingencies [Line Items]
Summary of Undiscounted Future Expected Payments for Power Purchase Agreements That Have Been Approved by the CPUC and Have Completed Major Milestones for Construction	At December 31, 2016 , the undiscounted future minimum expected payments for the SCE power purchase agreements that have been approved by the CPUC and have completed major milestones for construction were as follows: (in millions) Renewable Energy Contracts QF Power Purchase Agreements Other Purchase Agreements 2017 $ 1,516 $ 187 $ 769 2018 1,606 148 604 2019 1,704 87 516 2020 1,776 39 472 2021 1,786 16 420 Thereafter 22,811 53 1,258 Total future commitments $ 31,199 $ 530 $ 4,039
Summary of Certain Future Other Commitments	The following summarizes the estimated minimum future commitments for SCE's other commitments: (in millions) 2017 2018 2019 2020 2021 Thereafter Total Other contractual obligations $ 156 $ 141 $ 103 $ 98 $ 82 $ 631 $ 1,211

Preferred and Preference Stoc42

Preferred and Preference Stock of Utility (Tables)	12 Months Ended
	Dec. 31, 2016
Stockholders' Equity Note [Abstract]
Schedule of Stock by Class [Table Text Block]	Preferred stock and preference stock is: Shares Redemption December 31, (in millions, except shares and per-share amounts) 2016 2015 Cumulative preferred stock $25 par value: 4.08% Series 650,000 $ 25.50 $ 16 $ 16 4.24% Series 1,200,000 25.80 30 30 4.32% Series 1,653,429 28.75 41 41 4.78% Series 1,296,769 25.80 33 33 Preference stock No par value: 6.50% Series D (cumulative) 1,250,000 100.00 — 125 6.25% Series E (cumulative) 350,000 1,000.00 350 350 5.625% Series F (cumulative) 190,004 2,500.00 475 475 5.10% Series G (cumulative) 160,004 2,500.00 400 400 5.75% Series H (cumulative) 110,004 2,500.00 275 275 5.375% Series J (cumulative) 130,004 2,500.00 325 325 5.45% Series K (cumulative) 120,004 2,500.00 300 — SCE's preferred and preference stock 2,245 2,070 Less issuance costs (54 ) (50 ) Edison International's preferred and preference stock of utility $ 2,191 $ 2,020

Accumulated Other Comprehensi43

Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Components of Accumulated Other Comprehensive Loss	The changes in accumulated other comprehensive loss, net of tax, consist of: Edison International SCE Years ended December 31, (in millions) 2016 2015 2016 2015 Beginning balance $ (56 ) $ (58 ) $ (22 ) $ (28 ) Pension and PBOP – net gain (loss): Other comprehensive (loss) income before reclassifications (4 ) (8 ) (2 ) 1 Reclassified from accumulated other comprehensive loss 1 6 10 3 5 Other 1 — 1 — Change 3 2 2 6 Ending balance $ (53 ) $ (56 ) $ (20 ) $ (22 ) 1 These items are included in the computation of net periodic pension and PBOP expense. See Note 8 for additional information.

Interest and Other Income and44

Interest and Other Income and Other Expenses (Tables)	12 Months Ended
	Dec. 31, 2016
Other Income and Expenses [Abstract]
Interest and Other Income and Other Expenses	Interest and other income and other expenses are as follows: Years ended December 31, (in millions) 2016 2015 2014 SCE interest and other income: Equity allowance for funds used during construction $ 74 $ 87 $ 65 Increase in cash surrender value of life insurance policies and life insurance benefits 39 26 36 Interest income 3 4 5 Other 7 6 16 Total SCE interest and other income 123 123 122 Other income of Edison International Parent and Other 1 — 51 25 Total Edison International interest and other income $ 123 $ 174 $ 147 SCE other expenses: Civic, political and related activities and donations $ (32 ) $ (35 ) $ (35 ) Other (12 ) (24 ) (44 ) Total SCE other expenses (44 ) (59 ) (79 ) Other expense of Edison International Parent and Other — — (1 ) Total Edison International other expenses $ (44 ) $ (59 ) $ (80 ) 1 Reflects Edison Capital's income related to the sale of affordable housing projects for the year ended December 31, 2015.

Supplemental Cash Flows Infor45

Supplemental Cash Flows Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flows Information	Supplemental cash flows information for continuing operations is: Edison International SCE Years ended December 31, (in millions) 2016 2015 2014 2016 2015 2014 Cash payments (receipts) for interest and taxes: Interest, net of amounts capitalized $ 504 $ 512 $ 504 $ 475 $ 478 $ 487 Tax payments (refunds), net 18 1 32 78 144 (88 ) Non-cash financing and investing activities: Dividends declared but not paid: Common stock $ 177 $ 156 $ 136 $ — $ — $ 147 Preferred and preference stock 12 14 18 12 14 18 Details of debt exchange: Pollution-control bonds redeemed (2.875%) — (203 ) — — (203 ) — Pollution-control bonds issued (1.875%) — 203 — — 203 — Notes issued under EME Settlement Agreement $ — $ — $ 418 $ — $ — $ —

Quarterly Financial Data (Una46

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Edison International's quarterly financial data is as follows: 2016 (in millions, except per-share amounts) Total Fourth Third Second First Operating revenue $ 11,869 $ 2,884 $ 3,767 $ 2,777 $ 2,440 Operating income 2,092 566 695 381 448 Income from continuing operations 1 1,413 347 451 310 305 Income (loss) from discontinued operations, net 12 13 — (2 ) 1 Net income attributable to common shareholders 1 1,311 329 421 280 281 Basic earnings (loss) per share 1 : Continuing operations $ 3.99 $ 0.97 $ 1.29 $ 0.87 $ 0.86 Discontinued operations 0.03 0.04 — (0.01 ) — Total $ 4.02 $ 1.01 $ 1.29 $ 0.86 $ 0.86 Diluted earnings (loss) per share 1 : Continuing operations $ 3.94 $ 0.96 $ 1.27 $ 0.86 $ 0.85 Discontinued operations 0.03 0.04 — (0.01 ) — Total $ 3.97 $ 1.00 $ 1.27 $ 0.85 $ 0.85 Dividends declared per share 1.9825 0.5425 0.4800 0.4800 0.4800 Common stock prices: High $ 78.72 $ 73.81 $ 78.72 $ 77.71 $ 72.34 Low 57.97 67.44 71.31 67.71 57.97 Close 71.99 71.99 72.25 77.67 71.89 1 Edison International adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income from continuing operations, as previously reported, was $449 million for the third quarter of 2016, $306 million for the second quarter of 2016 and $295 million for the first quarter of 2016. Net income attributable to common shareholders, as previously reported, was $419 million for the third quarter of 2016, $276 million for the second quarter of 2016 and $271 million for the first quarter of 2016. Basic EPS for continuing operations, as previously reported, was $1.29 for the third quarter of 2016, $0.86 for the second quarter of 2016 and $0.83 for the first quarter of 2016. Diluted EPS for continuing operations, as previously reported, was $1.27 for the third quarter of 2016, $0.85 for the second quarter of 2016 and $0.82 for the first quarter of 2016. 2015 (in millions, except per-share amounts) Total Fourth Third Second First Operating revenue $ 11,524 $ 2,341 $ 3,763 $ 2,908 $ 2,512 Operating income 2,008 340 608 524 538 Income (loss) from continuing operations 1 1,082 (47 ) 405 406 318 Income (loss) from discontinued operations, net 35 (8 ) 43 — — Net income (loss) attributable to common shareholders 1,020 (79 ) 421 379 299 Basic earnings (loss) per share: Continuing operations $ 3.02 $ (0.22 ) $ 1.16 $ 1.16 $ 0.92 Discontinued operations 0.11 (0.02 ) 0.13 — — Total $ 3.13 $ (0.24 ) $ 1.29 $ 1.16 $ 0.92 Diluted earnings (loss) per share: Continuing operations $ 2.99 $ (0.22 ) $ 1.15 $ 1.15 $ 0.91 Discontinued operations 0.11 (0.02 ) 0.13 — — Total $ 3.10 $ (0.24 ) $ 1.28 $ 1.15 $ 0.91 Dividends declared per share 1.7325 0.4800 0.4175 0.4175 0.4175 Common stock prices: High $ 69.59 $ 66.29 $ 63.18 $ 64.55 $ 69.59 Low 55.18 57.51 55.52 55.18 61.02 Close 59.21 59.21 63.07 55.58 62.47 1 In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions. SCE's quarterly financial data is as follows: 2016 (in millions) Total Fourth Third Second First Operating revenue $ 11,830 $ 2,874 $ 3,752 $ 2,768 $ 2,435 Operating income 2,217 594 721 429 472 Net income 1 1,499 359 466 349 325 Net income available for common stock 1 1,376 328 435 318 295 Common dividends declared 701 191 170 170 170 1 SCE adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income, as previously reported, was $466 million for the third quarter of 2016, $346 million for the second quarter of 2016 and $317 million for the first quarter of 2016. Net income available for common stock, as previously reported, was $435 million for the third quarter of 2016, $315 million for the second quarter of 2016 and $287 million for the first quarter of 2016. 2015 (in millions) Total Fourth Third Second First Operating revenue $ 11,485 $ 2,319 $ 3,757 $ 2,901 $ 2,508 Operating income 2,080 366 626 536 550 Net income 1 1,111 (51 ) 417 412 333 Net income available for common stock 998 (80 ) 389 384 305 Common dividends declared 611 170 147 147 147 1 In the fourth quarter of 2015, as result of the 2015 GRC Decision, SCE recorded a $382 million write-down of regulatory assets previously recorded for recovery of deferred income taxes from 2012 – 2014 incremental tax repair deductions.

Summary of Significant Accoun47

Summary of Significant Accounting Policies (Organization and Basis of Presentation) (Details) mi² in Thousands	12 Months Ended
	Dec. 31, 2016mi²
Electric Utility | SCE
Segment Reporting Information [Line Items]
Supply Of Electricity Area Covered (in square miles)	50

Summary of Significant Accoun48

Summary of Significant Accounting Policies (Cash Equivalents) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Cash and Cash Equivalents Items [Line Items]
Money market funds	$ 41	$ 37
Book balances reclassified to accounts payable	138	162
SCE
Cash and Cash Equivalents Items [Line Items]
Money market funds	18	8
Book balances reclassified to accounts payable	$ 136	$ 158

Summary of Significant Accoun49

Summary of Significant Accounting Policies (Emission Allowances) (Details) - SCE - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Other Current Assets
Significant Accounting Policies [Line Items]
GHG allowances	$ 113	$ 79
Other Current Liabilities
Significant Accounting Policies [Line Items]
GHG emission obligations	$ 95	$ 86

Summary of Significant Accoun50

Summary of Significant Accounting Policies (Property, Plant and Equipment) (Details) - SCE - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Depreciation	$ 1,520	$ 1,420	$ 1,330
Depreciation expense stated as a percent of average original cost of depreciable utility plant (percent)	3.80%	3.90%	4.00%
Estimated cost of debt and equity funds for construction, capitalized	$ 74	$ 87	$ 65
Interest and other income
Property, Plant and Equipment [Line Items]
Estimated cost of debt and equity funds for construction, capitalized	74	87	65
Interest expense
Property, Plant and Equipment [Line Items]
AFUDC debt capitalized during construction	$ 23	$ 31	$ 25
Generation plant
Property, Plant and Equipment [Line Items]
Weighted-Average Useful Lives	38 years
Distribution plant
Property, Plant and Equipment [Line Items]
Weighted-Average Useful Lives	43 years
Transmission plant
Property, Plant and Equipment [Line Items]
Weighted-Average Useful Lives	53 years
General plant and other
Property, Plant and Equipment [Line Items]
Weighted-Average Useful Lives	22 years
Minimum | Generation plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	10 years
Minimum | Distribution plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	20 years
Minimum | Transmission plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	40 years
Minimum | General plant and other
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	5 years
Maximum | Generation plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	57 years
Maximum | Distribution plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	60 years
Maximum | Transmission plant
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	65 years
Maximum | General plant and other
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	60 years

Summary of Significant Accoun51

Summary of Significant Accounting Policies (Impairment of Long-Lived Assets) (Details) - USD ($) $ in Millions	12 Months Ended			24 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2014
Jointly Owned Utility Plant Interests [Line Items]
Impairment and other charges	$ 21	$ 5	$ 157
SCE
Jointly Owned Utility Plant Interests [Line Items]
Impairment and other charges	$ 0	$ 0	163
San Onofre | SCE
Jointly Owned Utility Plant Interests [Line Items]
Impairment and other charges			163	$ 738
Impairment and other charges, net of tax			$ 72	$ 437

Summary of Significant Accoun52

Summary of Significant Accounting Policies (Goodwill) (Details) $ in Millions	Dec. 31, 2016USD ($)
Edison Energy Group
Goodwill [Line Items]
Goodwill	$ 78
SoCore Energy
Goodwill [Line Items]
Goodwill	$ 22

Summary of Significant Accoun53

Summary of Significant Accounting Policies (Nuclear Decommissioning and Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward
Beginning balance	$ 2,764
Ending balance	2,590	$ 2,764
SCE
Asset Retirement Obligation, Roll Forward
Beginning balance	2,762	2,819
Accretion	157	173
Revisions	(165)	(14)
Liabilities settled	(168)	(216)
Ending balance	$ 2,586	$ 2,762
Threshold period to be recognized as a loss for other-than-temporary impairment	2 months
SCE | Palo Verde, San Onofre Unit 1
Asset Retirement Obligation, Roll Forward
Recorded liability to decommission nuclear power facilities	$ 2,500
SCE | Palo Verde and San Onofre Units
Asset Retirement Obligation, Roll Forward
Estimated cost to decommission nuclear facilities	$ 6,300
Decommissioning cost escalated rates, low end (percent)	1.70%
Decommissioning cost escalated rates, high end (percent)	7.50%
Estimated annual net of tax earnings, low end (percent)	2.40%
Estimated annual net of tax earnings, high end (percent)	4.10%

Summary of Significant Accoun54

Summary of Significant Accounting Policies (Deferred Financing Costs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Regulatory assets	$ 7,455	$ 7,512
Unamortized debt issuance expense	81
SCE
Regulatory Assets [Line Items]
Regulatory assets	7,455	7,512
Unamortized debt issuance expense	71
Amortization of deferred financing costs charged to interest expense	27	28	$ 32
Edison International
Regulatory Assets [Line Items]
Amortization of deferred financing costs charged to interest expense	31	33	$ 36
Unamortized loss on reacquired debt | SCE
Regulatory Assets [Line Items]
Regulatory assets	184	201
Other long-term assets | SCE
Regulatory Assets [Line Items]
Unamortized debt issuance expense	7	7
Other long-term assets | Edison International
Regulatory Assets [Line Items]
Unamortized debt issuance expense	10	11
Long-term debt | SCE
Regulatory Assets [Line Items]
Unamortized debt issuance expense	71	77
Long-term debt | Edison International
Regulatory Assets [Line Items]
Unamortized debt issuance expense	$ 81	$ 81

Summary of Significant Accoun55

Summary of Significant Accounting Policies (Revenue Recognition) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
SCE
Significant Accounting Policies [Line Items]
Franchise fees billed to customers	$ 111	$ 138	$ 134

Summary of Significant Accoun56

Summary of Significant Accounting Policies (SCE Dividend Restrictions) (Details) - SCE $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Significant Accounting Policies [Line Items]
Minimum percentage of weighted-average common equity component authorization, set by CPUC (as a percent)	48.00%
Weighted-average common equity component authorization, set by CPUC remaining over number of months (in months)	13 months
Period for calculation of weighted average common equity component (months)	13 months
Weighted-average common equity component of total capitalization (as a percent)	50.40%
Capacity to pay additional dividends	$ 585
Restriction on net assets	$ 13,900

Summary of Significant Accoun57

Summary of Significant Accounting Policies (Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Basic earnings per share – continuing operations:
Income from continuing operations, net of tax									$ 1,299	$ 985	$ 1,427
Participating securities dividends									0	(1)	(1)
Income from continuing operations available to common shareholders									$ 1,299	$ 984	$ 1,426
Weighted average common shares outstanding (in shares)									326,000,000	326,000,000	326,000,000
Basic earnings per share – continuing operations (in dollars per share)	$ 0.97	$ 1.29	$ 0.87	$ 0.86	$ (0.22)	$ 1.16	$ 1.16	$ 0.92	$ 3.99	$ 3.02	$ 4.38
Diluted earnings per share – continuing operations:
Income from continuing operations, net of tax									$ 1,299	$ 985	$ 1,427
Participating securities dividends									0	(1)	(1)
Income from continuing operations available to common shareholders									1,299	984	1,426
Income impact of assumed conversions									1	1	1
Income from continuing operations available to common shareholders and assumed conversions									$ 1,300	$ 985	$ 1,427
Weighted average common shares outstanding (in shares)									326,000,000	326,000,000	326,000,000
Incremental shares from assumed conversions (in shares)									4,000,000	3,000,000	3,000,000
Adjusted weighted average shares - diluted (in shares)									330,000,000	329,000,000	329,000,000
Diluted earnings per share – continuing operations (in dollars per share)	$ 0.96	$ 1.27	$ 0.86	$ 0.85	$ (0.22)	$ 1.15	$ 1.15	$ 0.91	$ 3.94	$ 2.99	$ 4.33
Stock Compensation Plan
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive stock option awards excluded from earnings per share, number of shares									167,795	2,046,045	125,345

Summary of Significant Accoun58

Summary of Significant Accounting Policies (Redeemable Noncontrolling Interest) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Redeemable Noncontrolling Interest [Line Items]
Assets	$ 51,319	$ 50,229
Liabilities	37,127	36,835
Unnamed subsidiary
Redeemable Noncontrolling Interest [Line Items]
Assets	74	82
Liabilities	23	32
Net income	$ 9	$ 16

Summary of Significant Accoun59

Summary of Significant Accounting Policies (New Accounting Guidance) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	$ 81
Accounting standards update on debt issuance costs | Other long-term assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		$ (81)
Accounting standards update on debt issuance costs | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		81
Accounting standards update to simplify the accounting for share-based payments | Early adoption using modified retrospective approach
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Income tax expense	28
Accounting standards update to simplify the accounting for share-based payments | Retained Earnings | Early adoption using modified retrospective approach
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect adjustment		42
SCE
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	71
SCE | Other long-term assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	7	7
SCE | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	71	77
SCE | Accounting standards update on debt issuance costs | Other long-term assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		(77)
SCE | Accounting standards update on debt issuance costs | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs		77
SCE | Accounting standards update to simplify the accounting for share-based payments | Early adoption using modified retrospective approach
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Income tax expense	$ 13
SCE | Accounting standards update to simplify the accounting for share-based payments | Retained Earnings | Early adoption using modified retrospective approach
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect adjustment		$ 6

Property, Plant and Equipment60

Property, Plant and Equipment (Schedule of Property, Plant and Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Accumulated depreciation	$ (9,000)	$ (8,548)
Total utility property, plant and equipment	36,806	34,945
SCE
Property, Plant and Equipment [Line Items]
Distribution	22,332	20,871
Transmission	12,549	11,592
Generation	3,376	3,138
General plant and other	4,633	4,543
Accumulated depreciation	(9,000)	(8,548)
Total utility property, plant and equipment, Gross	33,890	31,596
Construction work in progress	2,790	3,218
Nuclear fuel, at amortized cost	126	131
Total utility property, plant and equipment	$ 36,806	$ 34,945

Property, Plant and Equipment61

Property, Plant and Equipment (Textual) (Details) - SCE - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Capitalized software costs	$ 1,400	$ 1,400
Capitalized software, accumulated amortization	800	900
Capitalized software, amortization expense	249	$ 268	$ 271
Capitalized software, estimated annual amortization expense for 2017 through 2021	$ 243
Capitalized software costs | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	5 years
Capitalized software costs | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Lives	15 years

Property, Plant and Equipment62

Property, Plant and Equipment (Jointly Owned Utility Projects) (Details) - SCE - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Jointly Owned Utility Plant Interests [Line Items]
Nuclear Fuel (at amortized cost)	$ 126	$ 131
Eldorado
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	235
Construction Work in Progress	10
Accumulated Depreciation	21
Nuclear Fuel (at amortized cost)	0
Net Book Value	$ 224
Ownership Interest (percent)	59.00%
Pacific Intertie
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 192
Construction Work in Progress	21
Accumulated Depreciation	80
Nuclear Fuel (at amortized cost)	0
Net Book Value	$ 133
Ownership Interest (percent)	50.00%
Palo Verde (nuclear)
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 1,959
Construction Work in Progress	62
Accumulated Depreciation	1,547
Nuclear Fuel (at amortized cost)	126
Net Book Value	$ 600
Ownership Interest (percent)	16.00%
Total
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 2,386
Construction Work in Progress	93
Accumulated Depreciation	1,648
Nuclear Fuel (at amortized cost)	126
Net Book Value	$ 957

Variable Interest Entities (Var

Variable Interest Entities (Variable Interest in VIEs that are not Consolidated) (Details) - SCE	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesMW	Dec. 31, 2015USD ($)$ / sharesMW
Series F Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)	5.625%
Series G Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)	5.10%
Series H Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)	5.75%
Series J Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)	5.375%
Series K Preferred Stock
Unconsolidated Trust
Security dividend rate, (as a percent)	5.45%
Variable Interest Entity, Not Primary Beneficiary | SCE Power Purchase Contracts
Details of projects or entities
Power generating capacity for majority interest (in megawatts) | MW	4,353	4,062
Payments to unconsolidated VIEs for power purchase contracts	$ 788,000,000	$ 640,000,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust I
Unconsolidated Trust
Common stock	$ 10,000	10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust I | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)	5.625%
Liquidation preference	$ 475,000,000	$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 25	$ 25
Common stock	$ 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%
Liquidation preference	$ 475,000,000	$ 475,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust II
Unconsolidated Trust
Common stock	$ 10,000	10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust II | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)	5.10%
Liquidation preference	$ 400,000,000	$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 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%
Liquidation preference	$ 400,000,000	$ 400,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust III
Unconsolidated Trust
Common stock	$ 10,000	10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust III | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)	5.75%
Liquidation preference	$ 275,000,000	$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 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%
Liquidation preference	$ 275,000,000	$ 275,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust IV
Unconsolidated Trust
Common stock	$ 10,000	10,000
Variable Interest Entity, Not Primary Beneficiary | SCE Trust IV | Trust Securities
Unconsolidated Trust
Security dividend rate, (as a percent)	5.375%
Liquidation preference	$ 325,000,000	$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 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%
Liquidation preference	$ 325,000,000	$ 325,000,000
Liquidation value (in dollars per share) | $ / shares	$ 2,500
Variable Interest Entity, Not Primary Beneficiary | SCE Trust V
Unconsolidated Trust
Common stock	$ 10,000
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
Liquidation value (in dollars per share) | $ / shares	$ 25
Common stock	$ 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
Liquidation value (in dollars per share) | $ / shares	$ 2,500

Variable Interest Entities (Sum

Variable Interest Entities (Summary of Trusts' Income Statement) (Details) - SCE - Variable Interest Entity, Not Primary Beneficiary - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
SCE Trust I
Variable Interest Entity [Line Items]
Dividend income	$ 27	$ 27	$ 27
Dividend distributions	27	27	27
SCE Trust II
Variable Interest Entity [Line Items]
Dividend income	20	20	20
Dividend distributions	20	20	20
SCE Trust III
Variable Interest Entity [Line Items]
Dividend income	16	16	13
Dividend distributions	16	16	$ 13
SCE Trust IV
Variable Interest Entity [Line Items]
Dividend income	17	6
Dividend distributions	17	$ 6
SCE Trust V
Variable Interest Entity [Line Items]
Dividend income	13
Dividend distributions	$ 13

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value by Level) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Assets at fair value
Nuclear decommissioning trusts	$ 4,242	$ 4,331
SCE
Assets at fair value
Nuclear decommissioning trusts	$ 4,242	$ 4,331	$ 4,799	$ 4,494
Liabilities at fair value
Percentage of equity investments located in the United States (as a percent)	70.00%	70.00%
Collateralized mortgage obligations and other asset backed securities	$ 79	$ 111
Payables, net, related to investments	(127)	(24)
SCE | Fair Value, Measurements, Recurring
Assets at fair value
Derivative contracts	74	163
Other	33	28
Nuclear decommissioning trusts	4,369	4,355
Total assets	4,476	4,546
Liabilities at fair value
Derivative contracts	1,157	1,318
Netting and Collateral	0	15
Total liabilities	1,157	1,318
Net assets (liabilities)	3,319	3,228
SCE | Fair Value, Measurements, Recurring | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,547	1,460
SCE | Fair Value, Measurements, Recurring | Fixed Income
Assets at fair value
Nuclear decommissioning trusts	2,616	2,723
SCE | Fair Value, Measurements, Recurring | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	206	172
SCE | Fair Value, Measurements, Recurring | Level 1
Assets at fair value
Derivative contracts	0	0
Other	33	28
Nuclear decommissioning trusts	2,448	2,498
Total assets	2,481	2,526
Liabilities at fair value
Derivative contracts	0	0
Total liabilities	0	0
Net assets (liabilities)	2,481	2,526
SCE | Fair Value, Measurements, Recurring | Level 1 | Stocks
Assets at fair value
Nuclear decommissioning trusts	1,547	1,460
SCE | Fair Value, Measurements, Recurring | Level 1 | Fixed Income
Assets at fair value
Nuclear decommissioning trusts	865	947
SCE | Fair Value, Measurements, Recurring | Level 1 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	36	91
SCE | Fair Value, Measurements, Recurring | Level 2
Assets at fair value
Derivative contracts	6	0
Other	0	0
Nuclear decommissioning trusts	1,921	1,857
Total assets	1,927	1,857
Liabilities at fair value
Derivative contracts	0	22
Total liabilities	0	22
Net assets (liabilities)	1,927	1,835
SCE | Fair Value, Measurements, Recurring | Level 2 | Stocks
Assets at fair value
Nuclear decommissioning trusts	0	0
SCE | Fair Value, Measurements, Recurring | Level 2 | Fixed Income
Assets at fair value
Nuclear decommissioning trusts	1,751	1,776
SCE | Fair Value, Measurements, Recurring | Level 2 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	170	81
SCE | Fair Value, Measurements, Recurring | Level 3
Assets at fair value
Derivative contracts	68	163
Other	0	0
Nuclear decommissioning trusts	0	0
Total assets	68	163
Liabilities at fair value
Derivative contracts	1,157	1,311
Total liabilities	1,157	1,311
Net assets (liabilities)	(1,089)	(1,148)
SCE | Fair Value, Measurements, Recurring | Level 3 | Stocks
Assets at fair value
Nuclear decommissioning trusts	0	0
SCE | Fair Value, Measurements, Recurring | Level 3 | Fixed Income
Assets at fair value
Nuclear decommissioning trusts	0	0
SCE | Fair Value, Measurements, Recurring | Level 3 | Short-term investments, primarily cash equivalents
Assets at fair value
Nuclear decommissioning trusts	$ 0	$ 0

Fair Value Measurements (Textua

Fair Value Measurements (Textual) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 41	$ 37
Edison International Parent and Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 23	$ 29

Fair Value Measurements (Level

Fair Value Measurements (Level 3 Rollforward) (Details) - SCE - Level 3 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value Disclosures Level 3 [Roll Forward]
Fair value of net liabilities at beginning of period	$ (1,148)	$ (902)
Total realized/unrealized gains (losses):
Included in regulatory assets and liabilities	59	(246)
Fair value of net liabilities at end of period	(1,089)	(1,148)
Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period	$ (70)	$ (311)

Fair Value Measurements (Quanti

Fair Value Measurements (Quantitative Information About Level 3 Fair Value Measurements) (Details) - SCE - Level 3 $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / MWhMW	Dec. 31, 2015USD ($)$ / MWhMW
Congestion revenue rights | Market simulation model and auction prices
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 67	$ 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	3,708	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	22,840	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)	3.65	0
Congestion revenue rights | Market simulation model and auction prices | Power prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value Inputs, price level ($ per MWh)	99.58	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)	2.51	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)	4.87	5.72
Tolling | Option model
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value, Assets | $	$ 0	$ 10
Fair Value, Liabilities | $	$ 1,154	$ 1,297
Tolling | Option model | Power prices | Minimum
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value Inputs, price level ($ per MWh)	23.40	24.15
Expected volatility rate (as a percent)	29.00%	26.00%
Tolling | Option model | Power prices | Maximum
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value Inputs, price level ($ per MWh)	51.24	46.93
Expected volatility rate (as a percent)	71.00%	38.00%
Tolling | Option model | Power prices | Weighted Average
Quantitative Information About Level 3 Measurements [Line Items]
Fair Value Inputs, price level ($ per MWh)	34.70	34.80
Expected volatility rate (as a percent)	40.00%	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)	48.00%	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%

Fair Value Measurements (Fair69

Fair Value Measurements (Fair Value of Long-Term Debt Recorded at Carrying Value) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value of Long-Term Debt Recorded at Carrying Value
Carrying Value	$ 11,156	$ 11,178
Fair Value	12,368	12,252
SCE
Fair Value of Long-Term Debt Recorded at Carrying Value
Carrying Value	10,333	10,539
Fair Value	$ 11,539	$ 11,592

Debt and Credit Agreements (Lon

Debt and Credit Agreements (Long-term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Current portion of long-term debt	$ (981)	$ (295)
Long-term debt	10,175	10,883
Edison International Parent and Other
Debt Instrument [Line Items]
Other long-term debt	32	31
Current portion of long-term debt	(402)	(216)
Unamortized debt discount and issuance costs, net	(9)	(6)
Long-term debt	421	423
Edison International Parent and Other | Debentures and notes
Debt Instrument [Line Items]
Long-term debt	$ 800	614
Edison International Parent and Other | Debentures and notes | Minimum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	2.95%
Edison International Parent and Other | Debentures and notes | Maximum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	3.75%
SCE
Debt Instrument [Line Items]
Current portion of long-term debt	$ (579)	(79)
Unamortized debt discount and issuance costs, net	(105)	(113)
Long-term debt	9,754	10,460
SCE | Debentures and notes
Debt Instrument [Line Items]
Long-term debt	$ 307	307
SCE | Debentures and notes | Minimum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	5.06%
SCE | Debentures and notes | Maximum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	6.65%
SCE | First and refunding mortgage bonds
Debt Instrument [Line Items]
Long-term debt	$ 9,357	9,436
SCE | First and refunding mortgage bonds | Minimum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	1.125%
SCE | First and refunding mortgage bonds | Maximum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	6.05%
SCE | Pollution-control bonds
Debt Instrument [Line Items]
Long-term debt	$ 774	$ 909
SCE | Pollution-control bonds | Minimum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	1.375%
SCE | Pollution-control bonds | Maximum
Debt Instrument [Line Items]
Interest rate on debt (as a percent)	5.00%

Debt and Credit Agreements (L71

Debt and Credit Agreements (Long-term debt maturities) (Details) $ in Millions	Dec. 31, 2016USD ($)
Debt Instrument [Line Items]
2,017	$ 981
2,018	482
2,019	82
2,020	80
2,021	580
SCE
Debt Instrument [Line Items]
2,017	579
2,018	479
2,019	79
2,020	79
2,021	$ 579

Debt and Credit Agreements (Tex

Debt and Credit Agreements (Textual) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Jan. 31, 2017	Dec. 31, 2015
Debt Instrument [Line Items]
Carrying value	$ 11,156,000,000		$ 11,178,000,000
Multi-year credit facilities
Debt Instrument [Line Items]
Commitment	1,250,000,000
Outstanding borrowings	$ (538,000,000)		$ (646,000,000)
Weighted average interest rate (as a percent)	0.97%		0.78%
Outstanding letters of credit	$ 0
Indirect subsidiaries | Non-recourse debt financing to support equity investments in solar rooftop projects
Debt Instrument [Line Items]
Carrying value	$ 22,000,000		$ 25,000,000
Debt instrument (term)	7 years
Weighted average interest rate on long term debt	3.50%		3.11%
Percentage of taxable profits and losses and tax credits	99.00%
Period following the completion of the portfolio of projects (term)	6 years
Priority return on investment (percent)	2.00%
Percentage of taxable profits and losses and cash flow	5.00%
Call option, period	9 months
Period after project completion	5 years
Indirect subsidiary of Edison Energy Group | Non-recourse debt financing to support equity investments in solar rooftop projects
Debt Instrument [Line Items]
Carrying value	$ 10,000,000		$ 6,000,000
Weighted average interest rate on long term debt	9.00%		9.00%
SCE
Debt Instrument [Line Items]
Carrying value	$ 10,333,000,000		$ 10,539,000,000
SCE | Multi-year credit facilities
Debt Instrument [Line Items]
Commitment	2,750,000,000
Outstanding borrowings	(769,000,000)
Outstanding letters of credit	(91,000,000)
SCE | Agreement | Subsequent event
Debt Instrument [Line Items]
Debt, face amount		$ 300,000,000
Interest rate on debt (as a percent)		1.483%
SCE | Pollution-control bonds | Subsequent event
Debt Instrument [Line Items]
Debt, face amount		$ 135,000,000
Interest rate on debt (as a percent)		2.625%
Commercial paper | SCE | Multi-year credit facilities
Debt Instrument [Line Items]
Outstanding borrowings	$ (769,000,000)		$ (49,000,000)
Weighted average interest rate (as a percent)	0.90%		0.51%
Letters of credit | SCE | Multi-year credit facilities
Debt Instrument [Line Items]
Outstanding letters of credit	$ (91,000,000)
Letters of credit expiration period	12 months

Debt and Credit Agreements (Sum

Debt and Credit Agreements (Summary for status of credit facilities) (Details) - Multi-year credit facilities - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Commitment	$ 1,250,000,000
Outstanding borrowings	(538,000,000)	$ (646,000,000)
Outstanding letters of credit	0
Amount available	712,000,000
SCE
Line of Credit Facility [Line Items]
Commitment	2,750,000,000
Outstanding borrowings	(769,000,000)
Outstanding letters of credit	(91,000,000)
Amount available	$ 1,890,000,000

Derivative Instruments (Textual

Derivative Instruments (Textual) (Details) - SCE - Electric Utility - Economic hedges - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Derivatives
Aggregate fair value of all derivative liabilities with credit-risk-related contingent features	$ 12,000,000	$ 38,000,000
Posted collateral	12,000,000	$ 0
Potential amount of collateral to be posted if contingencies triggered	4,000,000
Payables
Derivatives
Potential amount of collateral to be posted if contingencies triggered	$ 4,000,000

Derivative Instruments (Balance

Derivative Instruments (Balance Sheet Disclosures) (Details) - SCE - Commodity derivative contracts - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Electric Utility
Derivative Assets
Gross amounts recognized	$ 75	$ 165
Gross amounts offset in consolidated balance sheets	(1)	(2)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	74	163
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1,158	1,335
Gross amounts offset in consolidated balance sheets	(1)	(2)
Cash collateral posted	0	(15)
Net amounts presented in the consolidated balance sheets	1,157	1,318
Net Liability
Gross amounts recognized	1,083	1,170
Gross amounts offset in consolidated balance sheets	0	0
Cash collateral posted	0	(15)
Net amounts presented in the consolidated balance sheets	1,083	1,155
Derivative Assets, Short-Term | Electric Utility
Derivative Assets
Gross amounts recognized	74	81
Gross amounts offset in consolidated balance sheets	(1)	(2)
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	73	79
Derivative Assets, Long-Term | Electric Utility
Derivative Assets
Gross amounts recognized	1	84
Gross amounts offset in consolidated balance sheets	0	0
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	1	84
Derivative Liability, Short-Term | Electric Utility
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	217	235
Gross amounts offset in consolidated balance sheets	(1)	(2)
Cash collateral posted	0	(15)
Net amounts presented in the consolidated balance sheets	216	218
Derivative Liability, Long-Term | Electric Utility
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	941	1,100
Gross amounts offset in consolidated balance sheets	0	0
Cash collateral posted	0	0
Net amounts presented in the consolidated balance sheets	941	1,100
Other Current Liabilities
Net Liability
Cash collateral	$ 2
Other Current Assets
Net Liability
Cash collateral		$ 31

Derivative Instruments (Summari

Derivative Instruments (Summarization of Economic Hedging Activities) (Details) - SCE - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses	$ (59)	$ (148)	$ (57)
Unrealized gains (losses)	$ 84	$ (182)	$ (147)

Derivative Instruments (Notiona

Derivative Instruments (Notional Values) (Details) - SCE - Electric Utility - Gross amounts recognized MWh in Thousands	Dec. 31, 2016BcfeMWh	Dec. 31, 2015BcfeMWh
Electricity options, swaps and forwards (GWh)
Derivatives
Notional volumes of derivative instruments	1,816	6,221
Natural gas options, swaps and forwards (Bcf)
Derivatives
Notional volumes of derivative instruments | Bcfe	36	32
Congestion revenue rights (GWh)
Derivatives
Notional volumes of derivative instruments	93,319	109,740
Tolling arrangements (GWh)
Derivatives
Notional volumes of derivative instruments	61,093	70,663

Income Taxes (Source of Income

Income Taxes (Source of Income (Loss) Before Income Taxes) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income from continuing operations before income taxes	$ 1,590	$ 1,568	$ 1,979
Income (loss) from discontinued operations before income taxes	1	15	(525)
Income before income tax	$ 1,591	$ 1,583	$ 1,454

Income Taxes (Components of Inc

Income Taxes (Components of Income Tax Expense (Benefit) by Location) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current:
Federal	$ (46)	$ 18	$ (99)
State	33	19	20
Total current	(13)	37	(79)
Deferred:
Federal	176	340	454
State	14	109	68
Total deferred	190	449	522
Total continuing operations	177	486	443
Discontinued operations	(11)	(21)	(710)
Total	166	465	(267)
SCE
Current:
Federal	75	72	(89)
State	93	127	101
Total current	168	199	12
Deferred:
Federal	112	298	476
State	(24)	10	(14)
Total deferred	88	308	462
Total continuing operations	256	507	474
Discontinued operations	0	0	0
Total	$ 256	$ 507	$ 474

Income Taxes (Components of Net

Income Taxes (Components of Net Accumulated Deferred Income Tax Liability) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2013
Deferred tax assets:
Property and software related	$ 549	$ 675
Nuclear decommissioning trust assets in excess of nuclear ARO liability	348	360
Loss and credit carryforwards	1,418	1,388	$ 2,200
Regulatory balancing accounts	15	21
Pension and PBOPs	300	337
Other	419	499
Sub-total	3,049	3,280
Less valuation allowance	24	32
Total	3,025	3,248
Deferred tax liabilities:
Property-related	10,330	9,606
Capitalized software costs	237	207
Regulatory balancing accounts	134	202
Nuclear decommissioning trust assets	348	360
PBOPs	13	71
Other	202	189
Total	11,264	10,635
Accumulated deferred income tax liability, net	8,239	7,387
SCE
Deferred tax assets:
Property and software related	548	675
Nuclear decommissioning trust assets in excess of nuclear ARO liability	348	360
Loss and credit carryforwards	0	0
Regulatory balancing accounts	15	21
Pension and PBOPs	93	154
Other	408	411
Sub-total	1,412	1,621
Less valuation allowance	0	0
Total	1,412	1,621
Deferred tax liabilities:
Property-related	10,330	9,600
Capitalized software costs	237	207
Regulatory balancing accounts	134	202
Nuclear decommissioning trust assets	348	360
PBOPs	13	71
Other	148	161
Total	11,210	10,601
Accumulated deferred income tax liability, net	$ 9,798	$ 8,980

Income Taxes (Operating Loss an

Income Taxes (Operating Loss and Tax Carryforward) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Tax Credit Carryforward [Line Items]
Loss Carryforwards, Expiring 2017 to 2035	$ 1,095
Loss Carryforwards, No expiration date	0
Loss Carryforwards	1,095
Credit Carryforward, Expiring 2017 to 2035	430
Credit Carryforward, No expiration date	69
Credit Carryforwards	499
Unrecognized tax benefits	471	$ 529	$ 576	$ 815
SCE
Tax Credit Carryforward [Line Items]
Loss Carryforwards, Expiring 2017 to 2035	20
Loss Carryforwards, No expiration date	0
Loss Carryforwards	20
Credit Carryforward, Expiring 2017 to 2035	25
Credit Carryforward, No expiration date	37
Credit Carryforwards	62
Unrecognized tax benefits	371	$ 353	$ 441	$ 532
Loss And Credit Carryforwards
Tax Credit Carryforward [Line Items]
Unrecognized tax benefits	176
Loss And Credit Carryforwards | SCE
Tax Credit Carryforward [Line Items]
Unrecognized tax benefits	$ 82

Income Taxes (Textual) (Details

Income Taxes (Textual) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Apr. 30, 2016	Jun. 30, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Line Items]
Less valuation allowance				$ 24
Valuation allowance for assets				8
Unrecognized tax benefits that would impact the effective tax rate			$ 440	347	$ 440
IRS Examination | Tax Years 2010 to 2012
Income Tax Disclosure [Line Items]
Federal tax liability					(94)
Disallowance of Repair Allowance Deduction
Income Tax Disclosure [Line Items]
Federal tax liability						$ (133)
Base rate offset			324		$ 324
Rate base offset amortization period (years)					27 years
Capistrano Wind | Affiliated Entity | Tax Allocation Agreement
Income Tax Disclosure [Line Items]
Due to affiliate under tax allocation agreements			210	242	$ 210
SCE
Income Tax Disclosure [Line Items]
Granted BRRBA reduction	$ 234
Refund		$ 133
After tax refund		$ 79
Unrecognized tax benefits that would impact the effective tax rate			256	$ 243	256
SCE | IRS Examination | Tax Years 2010 to 2012
Income Tax Disclosure [Line Items]
Federal tax liability					(100)
SCE | Disallowance of Repair Allowance Deduction
Income Tax Disclosure [Line Items]
Federal tax liability			382		382
Retained Earnings | Accounting standards update to simplify the accounting for share-based payments | Early adoption using modified retrospective approach
Income Tax Disclosure [Line Items]
Cumulative effect adjustment			42		42
Retained Earnings | Accounting standards update to simplify the accounting for share-based payments | Early adoption using modified retrospective approach | SCE
Income Tax Disclosure [Line Items]
Cumulative effect adjustment			$ 6		$ 6

Income Taxes (Tax Rate Reconcil

Income Taxes (Tax Rate Reconciliation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Line Items]
Income from continuing operations before income taxes	$ 1,590	$ 1,568	$ 1,979
Provision for income tax at federal statutory rate of 35%	556	549	693
Increase in income tax from:
Regulatory asset write-off	0	382	0
State tax, net of federal benefit	29	5	56
Property-related	(362)	(341)	(252)
Change related to uncertain tax positions	(4)	(67)	5
San Onofre OII settlement	0	0	(23)
Share-based compensation	(28)	0	0
Other	(14)	(42)	(36)
Total continuing operations	$ 177	$ 486	$ 443
Effective tax rate	11.10%	31.00%	22.40%
Federal statutory rate	35.00%	35.00%	35.00%
State
Increase in income tax from:
Share-based compensation	$ (4)
SCE
Income Tax Disclosure [Line Items]
Income from continuing operations before income taxes	1,755	$ 1,618	$ 2,039
Provision for income tax at federal statutory rate of 35%	614	566	714
Increase in income tax from:
Regulatory asset write-off	0	382	0
State tax, net of federal benefit	43	34	55
Property-related	(362)	(341)	(252)
Change related to uncertain tax positions	(8)	(94)	12
San Onofre OII settlement	0	0	(23)
Share-based compensation	(13)	0	0
Other	(18)	(40)	(32)
Total continuing operations	$ 256	$ 507	$ 474
Effective tax rate	14.60%	31.30%	23.20%
SCE | State
Increase in income tax from:
Share-based compensation	$ (1)

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits
Balance at January 1,	$ 529	$ 576	$ 815
Tax positions taken during the current year, Increases	36	54	65
Tax positions taken during a prior year, Increases	2	66	1
Tax positions taken during a prior year, Decreases	(96)	(165)	(143)
Tax positions taken during a prior year, Decreases for settlements during the period	0	(2)	(162)
Balance at December 31,	471	529	576
SCE
Reconciliation of Unrecognized Tax Benefits
Balance at January 1,	353	441	532
Tax positions taken during the current year, Increases	36	48	57
Tax positions taken during a prior year, Increases	0	23	0
Tax positions taken during a prior year, Decreases	(18)	(159)	(93)
Tax positions taken during a prior year, Decreases for settlements during the period	0	0	(55)
Balance at December 31,	$ 371	$ 353	$ 441

Income Taxes (Interest and Pena

Income Taxes (Interest and Penalties Related to Income Taxes) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Line Items]
Accrued interest and penalties	$ 128	$ 122
Net after-tax interest and penalties tax benefit	6	9	$ 41
SCE
Income Tax Disclosure [Line Items]
Accrued interest and penalties	41	40
Net after-tax interest and penalties tax benefit	$ 2	$ 14	$ 16

Compensation and Benefit Plan86

Compensation and Benefit Plans (Employee Savings Plan) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Contribution Plans [Line Items]
Employer contributions	$ 69	$ 73	$ 71
SCE
Defined Contribution Plans [Line Items]
Employer contributions	$ 68	$ 72	$ 70

Compensation and Benefit Plan87

Compensation and Benefit Plans (Textual) (Details) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Assumed average equity risk premium (percent)	5.00%
Forecasted return on private equity and opportunistic investments (percent)	2.00%
Performance incentive plan award (shares)	66
Share-based compensation, shares available for grant	32
Stock options
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Stock options, expiration period, years	10 years
Stock options, vesting period, years	4 years
Volatility period	71 months	71 months	72 months
Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected contributions	$ 136
Actuarial gain (loss)	$ 125	$ 149
Discount rate (percent)	3.94%	4.18%
Permissible range of asset class weights (percent)	3.00%
Publicly traded equity investments located in the US (percent)	69.00%	63.00%
Pension Plans | US Equities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	29.00%
Pension Plans | Non-US Equities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	17.00%
Pension Plans | Fixed Income
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	35.00%
Pension Plans | Opportunistic Alternative Investments
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	15.00%
Pension Plans | Other Investments
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	4.00%
Voluntary Employee Beneficiary Association (VEBA) | Non-US Equities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	5.00%
Voluntary Employee Beneficiary Association (VEBA) | Fixed Income
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	85.00%
Voluntary Employee Beneficiary Association (VEBA) | Opportunistic Alternative Investments
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	10.00%
Postretirement Benefits Other Than Pensions
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected contributions	$ 21
Eligibility age	55 years
Service period for eligibility (at least) (years)	10 years
Defined benefit obligation increase (decrease) during the period	$ (40)	$ (62)
Actuarial gain (loss)	110	500
Experience gains	165	300
(Loss) income from a (decrease) increase in the discount rate	$ (95)	$ 140
Discount rate (percent)	4.29%	4.55%	4.16%
Publicly traded equity investments located in the US (percent)	63.00%	71.00%
Postretirement Benefits Other Than Pensions | US Equities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	41.00%
Postretirement Benefits Other Than Pensions | Non-US Equities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	17.00%
Postretirement Benefits Other Than Pensions | Fixed Income
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	34.00%
Postretirement Benefits Other Than Pensions | Opportunistic Alternative Investments
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	7.00%
Postretirement Benefits Other Than Pensions | Other Investments
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (percent)	1.00%
SCE | Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected contributions	$ 85
Actuarial gain (loss)	$ 140	$ 143
Discount rate (percent)	3.94%	4.18%
SCE | Postretirement Benefits Other Than Pensions
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit obligation increase (decrease) during the period	$ (40)	$ (61)
Actuarial gain (loss)	$ 110	$ 500
Discount rate (percent)	4.29%	4.55%

Compensation and Benefit Plan88

Compensation and Benefit Plans (Plan Assets and Benefit Obligation) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Amounts recognized in the consolidated balance sheets consist of:
Long-term liabilities	$ (1,354,000,000)	$ (1,759,000,000)
Assumed health care cost trend rates:
Net loss reclassified from other comprehensive loss	0	0	$ 3,000,000
SCE
Amounts recognized in the consolidated balance sheets consist of:
Long-term liabilities	(896,000,000)	(1,284,000,000)
Pension Plans
Change in projected benefit obligation
Projected benefit obligation at beginning of year	4,374,000,000	4,517,000,000
Service cost	139,000,000	142,000,000
Interest cost	171,000,000	170,000,000
Actuarial gain	(125,000,000)	(149,000,000)
Benefits paid	(275,000,000)	(305,000,000)
Other	0	(1,000,000)
Projected benefit obligation at end of year	4,284,000,000	4,374,000,000	4,517,000,000
Change in plan assets
Fair value of plan assets at beginning of year	3,298,000,000	3,454,000,000
Actual return on plan assets	262,000,000	30,000,000
Employer contributions	103,000,000	119,000,000
Benefits paid	(275,000,000)	(305,000,000)
Fair value of plan assets at end of year	3,388,000,000	3,298,000,000	3,454,000,000
Funded status at end of year	(896,000,000)	(1,076,000,000)
Amounts recognized in the consolidated balance sheets consist of:
Long-term assets	2,000,000	0
Current liabilities	(50,000,000)	(27,000,000)
Long-term liabilities	(848,000,000)	(1,049,000,000)
Total liabilities	(896,000,000)	(1,076,000,000)
Amounts recognized in accumulated other comprehensive loss consist of:
Prior service cost	(1,000,000)	0
Net loss	(93,000,000)	(96,000,000)
Total amounts recognized in accumulated other comprehensive loss	(92,000,000)	(96,000,000)
Amounts recognized as a regulatory asset	574,000,000	675,000,000
Total not yet recognized as expense	666,000,000	771,000,000
Accumulated benefit obligation at end of year	4,138,000,000	4,200,000,000
Pension plans with an accumulated benefit obligation in excess of plan assets:
Projected benefit obligation	4,284,000,000	4,374,000,000
Accumulated benefit obligation	4,138,000,000	4,200,000,000
Fair value of plan assets	$ 3,388,000,000	$ 3,298,000,000
Weighted-average assumptions used to determine obligations at end of year:
Discount rate	3.94%	4.18%
Rate of compensation increase	4.00%	4.00%
Assumed health care cost trend rates:
Net loss	$ (92,000,000)	$ (96,000,000)
Pension Plans | Edison International
Assumed health care cost trend rates:
Long-term payable	124,000,000	123,000,000
Pension Plans | SCE
Change in projected benefit obligation
Projected benefit obligation at beginning of year	3,878,000,000	3,999,000,000
Service cost	132,000,000	133,000,000
Interest cost	150,000,000	150,000,000
Actuarial gain	(140,000,000)	(143,000,000)
Benefits paid	(229,000,000)	(261,000,000)
Other	0	0
Projected benefit obligation at end of year	3,791,000,000	3,878,000,000	3,999,000,000
Change in plan assets
Fair value of plan assets at beginning of year	3,080,000,000	3,217,000,000
Actual return on plan assets	239,000,000	27,000,000
Employer contributions	82,000,000	97,000,000
Benefits paid	(229,000,000)	(261,000,000)
Fair value of plan assets at end of year	3,172,000,000	3,080,000,000	3,217,000,000
Funded status at end of year	(619,000,000)	(798,000,000)
Amounts recognized in the consolidated balance sheets consist of:
Long-term assets	0	0
Current liabilities	(4,000,000)	(4,000,000)
Long-term liabilities	(615,000,000)	(794,000,000)
Total liabilities	(619,000,000)	(798,000,000)
Amounts recognized in accumulated other comprehensive loss consist of:
Prior service cost	0	0
Net loss	(24,000,000)	(27,000,000)
Total amounts recognized in accumulated other comprehensive loss	(24,000,000)	(27,000,000)
Amounts recognized as a regulatory asset	574,000,000	675,000,000
Total not yet recognized as expense	598,000,000	702,000,000
Accumulated benefit obligation at end of year	3,683,000,000	3,744,000,000
Pension plans with an accumulated benefit obligation in excess of plan assets:
Projected benefit obligation	3,791,000,000	3,878,000,000
Accumulated benefit obligation	3,683,000,000	3,744,000,000
Fair value of plan assets	$ 3,172,000,000	$ 3,080,000,000
Weighted-average assumptions used to determine obligations at end of year:
Discount rate	3.94%	4.18%
Rate of compensation increase	4.00%	4.00%
Assumed health care cost trend rates:
Net loss	$ (24,000,000)	$ (27,000,000)
Net loss reclassified from other comprehensive loss	20,000,000	18,000,000
Postretirement Benefits Other Than Pensions
Change in projected benefit obligation
Projected benefit obligation at beginning of year	2,350,000,000	2,784,000,000
Service cost	35,000,000	46,000,000	40,000,000
Interest cost	97,000,000	102,000,000	117,000,000
Special termination benefits	2,000,000	(2,000,000)
Plan Amendments	(6,000,000)	0
Actuarial gain	(110,000,000)	(500,000,000)
Plan participants' contributions	19,000,000	20,000,000
Benefits paid	(111,000,000)	(100,000,000)
Projected benefit obligation at end of year	2,276,000,000	2,350,000,000	2,784,000,000
Change in plan assets
Fair value of plan assets at beginning of year	2,036,000,000	2,086,000,000
Actual return on plan assets	137,000,000	6,000,000
Employer contributions	21,000,000	24,000,000
Plan participants' contributions	19,000,000	20,000,000
Benefits paid	(111,000,000)	(100,000,000)
Fair value of plan assets at end of year	2,102,000,000	2,036,000,000	$ 2,086,000,000
Funded status at end of year	(174,000,000)	(314,000,000)
Amounts recognized in the consolidated balance sheets consist of:
Current liabilities	(14,000,000)	(15,000,000)
Long-term liabilities	(160,000,000)	(299,000,000)
Total liabilities	(174,000,000)	(314,000,000)
Amounts recognized in accumulated other comprehensive loss consist of:
Total amounts recognized in accumulated other comprehensive loss	(4,000,000)	(4,000,000)
Amounts recognized as a regulatory asset	136,000,000	174,000,000
Total not yet recognized as expense	$ 140,000,000	$ 178,000,000
Weighted-average assumptions used to determine obligations at end of year:
Discount rate	4.29%	4.55%	4.16%
Assumed health care cost trend rates:
Rate assumed for following year	7.00%	7.50%
Ultimate rate	5.00%	5.00%
Net loss	$ (4,000,000)	$ (4,000,000)
Postretirement Benefits Other Than Pensions | SCE
Change in projected benefit obligation
Projected benefit obligation at beginning of year	2,341,000,000	2,775,000,000
Service cost	34,000,000	46,000,000	$ 40,000,000
Interest cost	97,000,000	102,000,000	117,000,000
Special termination benefits	2,000,000	(2,000,000)
Plan Amendments	(6,000,000)	0
Actuarial gain	(110,000,000)	(500,000,000)
Plan participants' contributions	19,000,000	20,000,000
Benefits paid	(111,000,000)	(100,000,000)
Projected benefit obligation at end of year	2,266,000,000	2,341,000,000	2,775,000,000
Change in plan assets
Fair value of plan assets at beginning of year	2,036,000,000	2,086,000,000
Actual return on plan assets	137,000,000	6,000,000
Employer contributions	21,000,000	24,000,000
Plan participants' contributions	19,000,000	20,000,000
Benefits paid	(111,000,000)	(100,000,000)
Fair value of plan assets at end of year	2,102,000,000	2,036,000,000	$ 2,086,000,000
Funded status at end of year	(164,000,000)	(305,000,000)
Amounts recognized in the consolidated balance sheets consist of:
Current liabilities	(13,000,000)	(15,000,000)
Long-term liabilities	(151,000,000)	(290,000,000)
Total liabilities	(164,000,000)	(305,000,000)
Amounts recognized in accumulated other comprehensive loss consist of:
Total amounts recognized in accumulated other comprehensive loss	0	0
Amounts recognized as a regulatory asset	136,000,000	174,000,000
Total not yet recognized as expense	$ 136,000,000	$ 174,000,000
Weighted-average assumptions used to determine obligations at end of year:
Discount rate	4.29%	4.55%
Assumed health care cost trend rates:
Rate assumed for following year	7.00%	7.50%
Ultimate rate	5.00%	5.00%
Net loss	$ 0	$ 0

Compensation and Benefit Plan89

Compensation and Benefit Plans (Expense Components) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension and Other Postretirement Benefits
Net loss reclassified from other comprehensive loss	$ 0	$ 0	$ 3,000,000
Pension Plans
Pension and Other Postretirement Benefits
Service cost	139,000,000	142,000,000
Interest cost	171,000,000	170,000,000
Other	10,000,000	14,000,000	9,000,000
Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Service cost	35,000,000	46,000,000	40,000,000
Interest cost	97,000,000	102,000,000	117,000,000
Expected return on plan assets	(112,000,000)	(116,000,000)	(108,000,000)
Settlement costs	2,000,000	1,000,000	3,000,000
Amortization of prior service cost	(2,000,000)	(12,000,000)	(36,000,000)
Amortization of net loss	0	3,000,000	6,000,000
Expense under accounting standards	20,000,000	24,000,000	22,000,000
SCE | Pension Plans
Pension and Other Postretirement Benefits
Service cost	132,000,000	133,000,000
Interest cost	150,000,000	150,000,000
Net loss reclassified from other comprehensive loss	20,000,000	18,000,000
Other	6,000,000	8,000,000	4,000,000
SCE | Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Service cost	34,000,000	46,000,000	40,000,000
Interest cost	97,000,000	102,000,000	117,000,000
Expected return on plan assets	(112,000,000)	(116,000,000)	(108,000,000)
Settlement costs	2,000,000	1,000,000	3,000,000
Amortization of prior service cost	(2,000,000)	(12,000,000)	(35,000,000)
Amortization of net loss	0	2,000,000	5,000,000
Expense under accounting standards	19,000,000	23,000,000	22,000,000
Continuing Operations | Pension Plans
Pension and Other Postretirement Benefits
Service cost	139,000,000	142,000,000	133,000,000
Interest cost	172,000,000	170,000,000	181,000,000
Expected return on plan assets	(220,000,000)	(233,000,000)	(229,000,000)
Settlement costs	0	0	45,000,000
Curtailment gain	0	0	(4,000,000)
Amortization of prior service cost	4,000,000	5,000,000	5,000,000
Amortization of net loss	27,000,000	40,000,000	12,000,000
Expense under accounting standards	122,000,000	124,000,000	143,000,000
Regulatory adjustment (deferred)	(21,000,000)	(6,000,000)	8,000,000
Total expense recognized	101,000,000	118,000,000	151,000,000
Continuing Operations | SCE | Pension Plans
Pension and Other Postretirement Benefits
Service cost	136,000,000	139,000,000	128,000,000
Interest cost	156,000,000	155,000,000	164,000,000
Expected return on plan assets	(205,000,000)	(217,000,000)	(213,000,000)
Settlement costs	0	0	42,000,000
Curtailment gain	0	0	0
Amortization of prior service cost	4,000,000	5,000,000	5,000,000
Amortization of net loss	23,000,000	35,000,000	7,000,000
Expense under accounting standards	114,000,000	117,000,000	133,000,000
Regulatory adjustment (deferred)	(21,000,000)	(6,000,000)	8,000,000
Total expense recognized	$ 93,000,000	$ 111,000,000	$ 141,000,000

Compensation and Benefit Plan90

Compensation and Benefit Plans (Changes in Plan Assets and Benefits Obligations Recognized in OCI) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Unrecognized prior service cost (credit) to be amortized	$ (2)
Pension Plans
Pension and Other Postretirement Benefits
Net loss (gain)	6	$ 7	$ 85
Amortization of net loss and other	(10)	(15)	(13)
Total recognized in other comprehensive loss	(4)	(8)	72
Total recognized in expense and other comprehensive loss	97	110	223
Unrecognized net loss to be amortized	19
Unrecognized prior service cost (credit) to be amortized	3
Amount of net loss expected to be reclassified from other comprehensive loss	10
SCE | Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Unrecognized prior service cost (credit) to be amortized	(2)
SCE | Pension Plans
Pension and Other Postretirement Benefits
Net loss (gain)	4	(9)	37
Amortization of net loss and other	(6)	(9)	(4)
Total recognized in other comprehensive loss	(2)	(18)	33
Total recognized in expense and other comprehensive loss	91	$ 93	$ 174
Unrecognized net loss to be amortized	15
Unrecognized prior service cost (credit) to be amortized	3
Amount of net loss expected to be reclassified from other comprehensive loss	$ 6

Compensation and Benefit Plan91

Compensation and Benefit Plans (Weighted Average Assumptions) (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Postretirement Benefits Other Than Pensions
Assumed health care cost trend rates:
Ultimate rate	5.00%	5.00%
Pension Plans
Pension and Other Postretirement Benefits
Discount rate	4.18%	3.85%	4.50%
Rate of compensation increase	4.00%	4.00%	4.00%
Expected long-term return on plan assets	7.00%	7.00%	7.00%
Continuing Operations | Postretirement Benefits Other Than Pensions
Pension and Other Postretirement Benefits
Discount rate	4.55%	4.16%	5.00%
Expected long-term return on plan assets	5.60%	5.50%	5.50%
Assumed health care cost trend rates:
Current year	7.50%	7.75%	7.75%
Ultimate rate	5.00%	5.00%	5.00%

Compensation and Benefit Plan92

Compensation and Benefit Plans (Expected Future Benefit Payments) (Details) $ in Millions	Dec. 31, 2016USD ($)
Pension Plans
Years ended December 31,
2,017	$ 346
2,018	332
2,019	344
2,020	341
2,021	341
2022 – 2026	1,566
Postretirement Benefits Other Than Pensions
Years ended December 31,
2,017	98
2,018	102
2,019	105
2,020	109
2,021	113
2022 – 2026	612
SCE | Pension Plans
Years ended December 31,
2,017	271
2,018	298
2,019	300
2,020	304
2,021	304
2022 – 2026	1,396
SCE | Postretirement Benefits Other Than Pensions
Years ended December 31,
2,017	98
2,018	102
2,019	105
2,020	109
2,021	112
2022 – 2026	$ 609

Compensation and Benefit Plan93

Compensation and Benefit Plans (Pension Plan Assets - Fair Value Levels) (Details) - Pension Plans - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension and Other Postretirement Benefits
Fair value of plan assets	$ 3,548	$ 3,368
Fair value NAV	1,284	1,232
Receivables and payables, net	(160)	(70)
Net plan assets available for benefits	3,388	3,298	$ 3,454
Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	1,103	971
Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	1,161	1,165
Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
U.S. government and agency securities
Pension and Other Postretirement Benefits
Fair value of plan assets	526	425
Fair value NAV	0	0
U.S. government and agency securities | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	217	127
U.S. government and agency securities | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	309	298
U.S. government and agency securities | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Corporate stocks
Pension and Other Postretirement Benefits
Fair value of plan assets	735	736
Fair value NAV	$ 0	$ 0
Corporate stocks | Russell Indexes
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	62.00%	59.00%
Corporate stocks | MSCI
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	38.00%	41.00%
Corporate stocks | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	$ 720	$ 720
Corporate stocks | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	15	16
Corporate stocks | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Corporate bonds
Pension and Other Postretirement Benefits
Fair value of plan assets	725	755
Fair value NAV	0	0
Corporate bonds | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Corporate bonds | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	725	755
Corporate bonds | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Common/collective funds
Pension and Other Postretirement Benefits
Fair value of plan assets	692	640
Fair value NAV	692	640
Common/collective funds | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Common/collective funds | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Common/collective funds | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Partnerships/joint ventures
Pension and Other Postretirement Benefits
Fair value of plan assets	333	325
Fair value NAV	333	325
Partnerships/joint ventures | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Partnerships/joint ventures | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Partnerships/joint ventures | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Other investment entities
Pension and Other Postretirement Benefits
Fair value of plan assets	253	263
Fair value NAV	253	263
Other investment entities | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Other investment entities | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Other investment entities | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Registered investment companies
Pension and Other Postretirement Benefits
Fair value of plan assets	130	121
Fair value NAV	6	4
Registered investment companies | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	124	117
Registered investment companies | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Registered investment companies | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Interest-bearing cash
Pension and Other Postretirement Benefits
Fair value of plan assets	42	6
Fair value NAV	0	0
Interest-bearing cash | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	42	6
Interest-bearing cash | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Interest-bearing cash | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Other
Pension and Other Postretirement Benefits
Fair value of plan assets	112	97
Fair value NAV	0	0
Other | Level 1
Pension and Other Postretirement Benefits
Fair value of plan assets	0	1
Other | Level 2
Pension and Other Postretirement Benefits
Fair value of plan assets	112	96
Other | Level 3
Pension and Other Postretirement Benefits
Fair value of plan assets	0	0
Collateralized mortgage obligations and other asset backed securities
Pension and Other Postretirement Benefits
Fair value of plan assets	76	123
Mortgage obligations and other asset backed securities, below investment grade	$ 27	$ 25
Equity index fund | S&P 500
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	45.00%	46.00%
Equity index fund | MSCI All Country World Index exUS
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	15.00%
Equity index fund | MSCI-EAFE
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage		16.00%
Undervalued Securities | Russell Indexes
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	15.00%	14.00%
Non-index fund
Pension and Other Postretirement Benefits
Performance percentage benchmark, percentage	23.00%	22.00%
Asset backed securities including distressed mortgages | Level 3
Pension and Other Postretirement Benefits
Actual plan asset allocations, percentage	4.00%	15.00%
Private equity and venture capital funds including branded consumer products, clean and information technology and healthcare | Level 3
Pension and Other Postretirement Benefits
Actual plan asset allocations, percentage	55.00%	51.00%
Publicly traded fixed income securities | Level 3
Pension and Other Postretirement Benefits
Actual plan asset allocations, percentage	22.00%	20.00%
Broad range of financial assets in all global markets | Level 3
Pension and Other Postretirement Benefits
Actual plan asset allocations, percentage	18.00%	14.00%
SCE
Pension and Other Postretirement Benefits
Net plan assets available for benefits	$ 3,172	$ 3,080	$ 3,217

Compensation and Benefit Plan94

Compensation and Benefit Plans (Effect of Change in One Percent) (Details) - Postretirement Benefits Other Than Pensions $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Effect on ABO of one-percentage-point increase in assumed health care cost trend rate	$ 244
Effect on ABO of one-percentage-point decrease in assumed health care cost trend rate	(200)
Effect on annual aggregate service and interest costs of one-percentage-point increase in assumed health care cost trend rate	11
Effect on annual aggregate service and interest costs of one-percentage-point decrease in assumed health care cost trend rate	(9)
SCE
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Effect on ABO of one-percentage-point increase in assumed health care cost trend rate	243
Effect on ABO of one-percentage-point decrease in assumed health care cost trend rate	(199)
Effect on annual aggregate service and interest costs of one-percentage-point increase in assumed health care cost trend rate	11
Effect on annual aggregate service and interest costs of one-percentage-point decrease in assumed health care cost trend rate	$ (9)

Compensation and Benefit Plan95

Compensation and Benefit Plans (Other Postretirement Plan Assets - Fair Value Levels) (Details) - Postretirement Benefits Other Than Pensions - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net plan assets available for benefits	$ 2,102	$ 2,036	$ 2,086
Collateralized mortgage obligations and other asset backed securities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Receivables and payables, net	$ 47	$ 27
Non-index U.S. equity fund
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual plan asset allocations, percentage	18.00%	17.00%
Municipal Notes
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	$ 76	$ 97
Russell Indexes | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Performance percentage benchmark, percentage		47.00%
Russell 1000 index | Common or collective equity funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Performance percentage benchmark, percentage	39.00%	38.00%
MSCI-EAFE | Equity index fund
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Performance percentage benchmark, percentage	39.00%	41.00%
MSCI All Country World Index | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Performance percentage benchmark, percentage	53.00%	53.00%
Level 3 | Private equity and venture capital funds including branded consumer products, clean and information technology and healthcare
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual plan asset allocations, percentage	59.00%	56.00%
Level 3 | Broad range of financial assets in all global markets
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual plan asset allocations, percentage	31.00%	21.00%
Level 3 | Asset backed securities including distressed mortgages
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual plan asset allocations, percentage	9.00%	23.00%
SCE
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	$ 2,133	$ 2,060
Fair value NAV	542	520
Receivables and payables, net	(31)	(24)
Net plan assets available for benefits	2,102	2,036	$ 2,086
SCE | U.S. government and agency securities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	281	242
Fair value NAV	0	0
SCE | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	230	222
Fair value NAV	0	0
SCE | Corporate notes and bonds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	877	867
Fair value NAV	0	0
SCE | Common/collective funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	462	424
Fair value NAV	462	424
SCE | Partnerships
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	79	93
Fair value NAV	79	93
SCE | Registered investment companies
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	49	63
Fair value NAV	1	3
SCE | Interest bearing cash
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	48	31
Fair value NAV	0	0
SCE | Other
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	107	118
Fair value NAV	0	0
SCE | Level 1
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	552	518
SCE | Level 1 | U.S. government and agency securities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	222	200
SCE | Level 1 | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	230	222
SCE | Level 1 | Corporate notes and bonds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 1 | Common/collective funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 1 | Partnerships
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 1 | Registered investment companies
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	48	60
SCE | Level 1 | Interest bearing cash
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	48	31
SCE | Level 1 | Other
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	4	5
SCE | Level 2
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	1,039	1,022
SCE | Level 2 | U.S. government and agency securities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	59	42
SCE | Level 2 | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 2 | Corporate notes and bonds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	877	867
SCE | Level 2 | Common/collective funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 2 | Partnerships
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 2 | Registered investment companies
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 2 | Interest bearing cash
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 2 | Other
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	103	113
SCE | Level 3
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | U.S. government and agency securities
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Corporate stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Corporate notes and bonds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Common/collective funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Partnerships
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Registered investment companies
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Interest bearing cash
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	0	0
SCE | Level 3 | Other
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair value of plan assets	$ 0	$ 0

Compensation and Benefit Plan96

Compensation and Benefit Plans (Expense and Tax Benefits of Stock Based Compensation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 34	$ 29	$ 40
Income tax benefits related to stock compensation expense	41	12	16
Excess tax benefits (expense)	0	15	15
Stock options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	14	14	16
Performance shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	13	7	16
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	6	7	7
Other
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	1	1
SCE
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	16	16	20
Income tax benefits related to stock compensation expense	20	7	8
Excess tax benefits (expense)	0	23	20
SCE | Stock options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	8	8
SCE | Performance shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	6	4	8
SCE | Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	4	4
SCE | Other
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 0	$ 0	$ 0

Compensation and Benefit Plan97

Compensation and Benefit Plans (Black-Scholes Option Pricing Model Assumptions) (Details) - Stock options	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected terms (in years)	5 years 10 months 24 days	5 years 10 months 24 days	6 years
Risk-free interest rate, minimum	1.20%	1.60%	1.80%
Risk-free interest rate, maximum	2.20%	2.10%	2.10%
Weighted-average expected dividend yield	2.90%	2.60%	2.70%
Expected volatility, minimum	17.20%	16.40%	17.80%
Expected volatility, maximum	17.50%	17.00%	19.10%
Weighted-average volatility	17.40%	16.50%	18.90%
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected dividend yield	2.50%	2.60%	2.40%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected dividend yield	3.00%	3.20%	2.70%

Compensation and Benefit Plan98

Compensation and Benefit Plans (Stock Option Activity) (Details) - Stock options $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesshares
Stock options
Beginning balance (number of options) | shares	12,866,597
Grants (number of options) | shares	2,120,009
Expired (number of options) | shares	0
Forfeited (number of options) | shares	(274,166)
Exercised (number of options) | shares	(3,167,939)
Ending balance (number of options) | shares	11,544,501
Vested and expected to vest (number of options) | shares	11,437,110
Exercisable (number of options) | shares	7,685,341
Exercise Price
Beginning balance, weighted average exercise price (dollars per share) | $ / shares	$ 45.93
Granted, weighted average exercise price (dollars per share) | $ / shares	67.41
Expired, weighted average exercise price (dollars per share) | $ / shares	0
Forfeited, weighted average exercise price (dollars per share) | $ / shares	64.02
Exercised, weighted average exercise price (dollars per share) | $ / shares	42.93
Ending balance, weighted average exercise price (dollars per share) | $ / shares	50.26
Vested and expected to vest, weighted average exercise price (dollars per share) | $ / shares	50.12
Exercisable, weighted average exercise price (dollars per share) | $ / shares	$ 43.99
Remaining Contractual Term (Years)
Outstanding at December 31, 2016 (term)	6 years 7 days
Vested and expected to vest at December 31, 2016 (term)	5 years 11 months 27 days
Exercisable at December 31, 2016 (term)	4 years 11 months 5 days
Aggregate Intrinsic Value (in millions)
Vested and expected to vest at December 31, 2016 | $	$ 250
Exercisable at December 31, 2016 | $	$ 215
SCE
Stock options
Beginning balance (number of options) | shares	5,840,057
Grants (number of options) | shares	959,478
Expired (number of options) | shares	0
Forfeited (number of options) | shares	(120,842)
Exercised (number of options) | shares	(1,705,053)
Transfers, net (number of options) | shares	(246,224)
Ending balance (number of options) | shares	4,727,416
Vested and expected to vest (number of options) | shares	4,667,784
Exercisable (number of options) | shares	2,782,770
Exercise Price
Beginning balance, weighted average exercise price (dollars per share) | $ / shares	$ 47.77
Granted, weighted average exercise price (dollars per share) | $ / shares	67.36
Expired, weighted average exercise price (dollars per share) | $ / shares	0
Forfeited, weighted average exercise price (dollars per share) | $ / shares	61.96
Exercised, weighted average exercise price (dollars per share) | $ / shares	44.59
Transfers, net, weighted average exercise price (dollars per share) | $ / shares	59.29
Ending balance, weighted average exercise price (dollars per share) | $ / shares	51.81
Vested and expected to vest, weighted average exercise price (dollars per share) | $ / shares	51.63
Exercisable, weighted average exercise price (dollars per share) | $ / shares	$ 44.04
Remaining Contractual Term (Years)
Outstanding at December 31, 2016 (term)	6 years 2 months 27 days
Vested and expected to vest at December 31, 2016 (term)	6 years 2 months 16 days
Exercisable at December 31, 2016 (term)	4 years 10 months 2 days
Aggregate Intrinsic Value (in millions)
Vested and expected to vest at December 31, 2016 | $	$ 95
Exercisable at December 31, 2016 | $	$ 78

Compensation and Benefit Plan99

Compensation and Benefit Plans (Unrecognized Compensation Costs) (Details) - Stock options $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Pension and Other Postretirement Benefits
Unrecognized compensation cost, net of expected forfeitures	$ 13
Weighted-average period (in years)	2 years 3 months 18 days
SCE
Pension and Other Postretirement Benefits
Unrecognized compensation cost, net of expected forfeitures	$ 8
Weighted-average period (in years)	2 years 3 months 18 days

Compensation and Benefit Pla100

Compensation and Benefit Plans (Supplemental Data on Stock Options) (Details) - Stock options - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date fair value per option granted (dollars per share)	$ 7.38	$ 7.54	$ 7.26
Fair value of options vested	$ 11	$ 20	$ 17
Cash used to purchase shares to settle options	220	170	300
Cash from participants to exercise stock options	136	113	205
Value of options exercised	84	57	95
Tax benefits from options exercised	$ 34	$ 23	$ 39
SCE
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date fair value per option granted (dollars per share)	$ 7.50	$ 7.53	$ 7.34
Fair value of options vested	$ 5	$ 11	$ 9
Cash used to purchase shares to settle options	118	69	181
Cash from participants to exercise stock options	77	45	125
Value of options exercised	41	24	56
Tax benefits from options exercised	$ 17	$ 10	$ 23

Compensation and Benefit Pla101

Compensation and Benefit Plans (Nonvested Performance Share Activity) (Details)	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Equity Awards
Restricted Stock Units
Beginning balance (number of shares)	57,779
Granted (number of shares)	0
Forfeited (number of shares)	(1,258)
Vested (number of shares)	(56,521)
Ending balance (number of shares)	0
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 61.18
Granted, weighted average grant date fair value (dollars per share) | $ / shares	0
Forfeited, weighted average grant date fair value (dollars per share) | $ / shares	60.83
Vested, weighted average grant date fair value (dollars per share) | $ / shares	61.18
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 0
Liability Awards
Restricted Stock Units
Beginning balance (number of shares)	165,629
Granted (number of shares)	111,754
Forfeited (number of shares)	(13,502)
Vested (number of shares)	(56,384)
Ending balance (number of shares)	207,497
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 68.44
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 84.30
SCE | Equity Awards
Restricted Stock Units
Beginning balance (number of shares)	32,463
Granted (number of shares)	0
Forfeited (number of shares)	(1,012)
Vested (number of shares)	(29,080)
Affiliate transfers, net (number of shares)	(2,371)
Ending balance (number of shares)	0
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 62.01
Granted, weighted average grant date fair value (dollars per share) | $ / shares	0
Forfeited, weighted average grant date fair value (dollars per share) | $ / shares	49.73
Vested, weighted average grant date fair value (dollars per share) | $ / shares	50.75
Affiliate transfers, net, weighted average grant date fair value (dollars per share) | $ / shares	72.10
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 0
SCE | Liability Awards
Restricted Stock Units
Beginning balance (number of shares)	90,393
Granted (number of shares)	50,599
Forfeited (number of shares)	(5,751)
Vested (number of shares)	(28,963)
Affiliate transfers, net (number of shares)	(9,611)
Ending balance (number of shares)	96,667
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 68.64
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 84.25

Compensation and Benefit Pla102

Compensation and Benefit Plans (Restricted Stock Unit Activity) (Details) - Restricted stock units	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Restricted Stock Units
Beginning balance (number of shares) | shares	248,143
Granted (number of shares) | shares	123,266
Forfeited (number of shares) | shares	(16,435)
Vested (number of shares) | shares	(9,579)
Affiliate transfers, net (number of shares) | shares	0
Ending balance (number of shares) | shares	345,395
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 57.89
Granted, weighted average grant date fair value (dollars per share) | $ / shares	67.42
Forfeited, weighted average grant date fair value (dollars per share) | $ / shares	63.73
Vested, weighted average grant date fair value (dollars per share) | $ / shares	52.01
Affiliate transfers, net, weighted average grant date fair value (dollars per share) | $ / shares	0
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 61.05
SCE
Restricted Stock Units
Beginning balance (number of shares) | shares	134,375
Granted (number of shares) | shares	55,800
Forfeited (number of shares) | shares	(7,580)
Vested (number of shares) | shares	(8,032)
Affiliate transfers, net (number of shares) | shares	(13,775)
Ending balance (number of shares) | shares	160,788
Weighted-Average Grant Date Fair Value
Beginning balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 58.13
Granted, weighted average grant date fair value (dollars per share) | $ / shares	67.37
Forfeited, weighted average grant date fair value (dollars per share) | $ / shares	61.45
Vested, weighted average grant date fair value (dollars per share) | $ / shares	56.53
Affiliate transfers, net, weighted average grant date fair value (dollars per share) | $ / shares	62.09
Ending balance, weighted average grant date fair value (dollars per share) | $ / shares	$ 60.80

Compensation and Benefit Pla103

Compensation and Benefit Plans (Workforce Reduction) (Details) - SCE - Employee Severance $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Restructuring Reserve [Roll Forward]
Balance at January 1, 2016	$ 22
Additions	21
Payments	(40)
Balance at December 31, 2016	$ 3

Investments (Amortized Cost and

Investments (Amortized Cost and Fair Value of Nuclear Decommissioning Trusts) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	$ 4,242	$ 4,331
SCE
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	4,242	4,331	$ 4,799	$ 4,494
Repurchase agreements payable	114	81
SCE | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	2,784	2,917
Fair Value	4,369	4,355
Decommissioning Trust Investments	4,242	4,331
SCE | Fair Value, Measurements, Recurring | Stocks
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	319	304
Fair Value	1,547	1,460
SCE | Fair Value, Measurements, Recurring | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	659	691
Fair Value	766	840
SCE | Fair Value, Measurements, Recurring | U.S. government and agency securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	1,131	1,070
Fair Value	1,191	1,128
SCE | Fair Value, Measurements, Recurring | Corporate bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	600	708
Fair Value	659	755
SCE | Fair Value, Measurements, Recurring | Short-term investments and receivables/payables
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Amortized Cost	75	144
Fair Value	$ 79	$ 148

Investments (Nuclear Decommissi

Investments (Nuclear Decommissioning Trusts) (Details) - SCE - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Investment Holdings [Line Items]
Unrealized holding gains, net of losses	$ 1,500	$ 1,400
Deferred income taxes related to unrealized gains	348
Nuclear decommissioning trusts	$ 3,900

Investments (Summary of Changes

Investments (Summary of Changes in Fair Value of the Nuclear Decommissioning Trust) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period	$ 4,331
Balance at end of period	4,242	$ 4,331
SCE
Summary Of Changes In The Fair Value [Roll Forward]
Balance at beginning of period	4,331	4,799	$ 4,494
Gross realized gains	92	326	197
Gross realized losses	(19)	(26)	(5)
Unrealized gains (losses)	44	(364)	75
Other-than-temporary impairments	(36)	(29)	(14)
Interest, dividends and other	116	115	118
Contributions	0	54	5
Income taxes	(58)	(64)	(62)
Decommissioning disbursements	(224)	(471)	(4)
Administrative expenses and other	(4)	(9)	(5)
Balance at end of period	$ 4,242	$ 4,331	$ 4,799

Investments (Acquisitions) (Det

Investments (Acquisitions) (Details) $ in Millions	Feb. 01, 2017USD ($)MWhproject	Dec. 31, 2015USD ($)business	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)
Investment Holdings [Line Items]
After tax charge related to the buy-out of an earn-out provision			$ 13
Minnesota solar garden development project | Subsequent event
Investment Holdings [Line Items]
Businesses acquired | project	4
Aggregate purchase price	$ 10.5
Power generating capacity of acquired projects (in megawatts) | MWh	28
Minnesota solar garden development project | Maximum
Investment Holdings [Line Items]
Purchase price				$ 41.9
Reimbursed project specific interconnection costs				$ 8.7
Series of Individually Immaterial Business Acquisitions
Investment Holdings [Line Items]
Businesses acquired | business		3
Aggregate purchase price		$ 100
Intangible Assets, Net (Including Goodwill)		$ 90

Regulatory Assets and Liabil108

Regulatory Assets and Liabilities (Textual) (Details) - SCE	Feb. 01, 2012	Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets, energy derivatives, low range of contract expiration (in years)		10 years
Regulatory assets, energy derivatives, high range of contract expiration (in years)		45 years
Regulatory assets related to deferred income taxes, recovery period, low range (in years)		1 year
Regulatory assets related to deferred income taxes, recovery period, high range (in years)		60 years
Low end of the range of remaining original amortization (in years)		10 years
High end of the range of remaining original amortization (in years)		35 years
San Onofre
Regulatory Assets [Line Items]
Return rate earned on assets included in rate base (as a percent)		2.62%	2.62%
Period for rate recovery	10 years
Unamortized investments, net
Regulatory Assets [Line Items]
Return rate earned on assets included in rate base (as a percent)		7.90%	7.90%
Unamortized investments, net | Legacy Meters
Regulatory Assets [Line Items]
Return rate earned on assets included in rate base (as a percent)		6.46%	6.46%

Regulatory Assets and Liabil109

Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Current regulatory assets	$ 350	$ 560
Long-term regulatory assets	7,455	7,512
SCE
Regulatory Assets [Line Items]
Current regulatory assets	350	560
Long-term regulatory assets	7,455	7,512
Total regulatory assets	7,805	8,072
SCE | Regulatory balancing accounts
Regulatory Assets [Line Items]
Current regulatory assets	135	382
Long-term regulatory assets	66	36
SCE | Energy derivatives
Regulatory Assets [Line Items]
Current regulatory assets	150	159
Long-term regulatory assets	947	1,027
SCE | Unamortized investments, net
Regulatory Assets [Line Items]
Current regulatory assets	49	0
Long-term regulatory assets	80	182
SCE | Other
Regulatory Assets [Line Items]
Current regulatory assets	16	19
Long-term regulatory assets	7	288
SCE | Deferred income taxes, net
Regulatory Assets [Line Items]
Long-term regulatory assets	4,478	3,757
SCE | Pensions and other postretirement benefits
Regulatory Assets [Line Items]
Long-term regulatory assets	710	849
SCE | San Onofre
Regulatory Assets [Line Items]
Long-term regulatory assets	857	1,043
SCE | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Long-term regulatory assets	184	201
SCE | Environmental remediation
Regulatory Assets [Line Items]
Long-term regulatory assets	$ 126	$ 129

Regulatory Assets and Liabil110

Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 756	$ 1,128
Long-term regulatory liabilities	5,726	5,676
SCE
Regulatory Liabilities [Line Items]
Current regulatory liabilities	756	1,128
Long-term regulatory liabilities	5,726	5,676
Total regulatory liabilities	6,482	6,804
SCE | Regulatory balancing accounts
Regulatory Liabilities [Line Items]
Current regulatory liabilities	736	1,106
Long-term regulatory liabilities	1,180	1,314
SCE | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	20	22
Long-term regulatory liabilities	60	79
SCE | Costs of removal
Regulatory Liabilities [Line Items]
Long-term regulatory liabilities	2,847	2,781
SCE | Recoveries in excess of ARO liabilities
Regulatory Liabilities [Line Items]
Long-term regulatory liabilities	$ 1,639	$ 1,502

Regulatory Assets and Liabil111

Regulatory Assets and Liabilities (Regulatory Balancing Accounts) (Details) - SCE - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Regulatory balancing accounts | Energy resource recovery account
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	$ (20)	$ (439)
Regulatory balancing accounts | New system generation balancing account
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(6)	(171)
Refunds of excess revenue | Significant components
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(1,715)	(2,002)
Refunds of excess revenue | Public purpose programs and energy efficiency programs
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(992)	(683)
Refunds of excess revenue | Base revenue requirement balancing account
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(426)	(319)
Refunds of excess revenue | Tax accounting memorandum account and pole loading
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(142)	(248)
Refunds of excess revenue | Department of Energy litigation memorandum account
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(122)	0
Refunds of excess revenue | Greenhouse gas auction revenue
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	31	(75)
Refunds of excess revenue | FERC balancing accounts
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	(69)	74
Refunds of excess revenue | Other
Regulatory Assets and Liabilities
Net Regulatory Assets Pertaining to Balancing Accounts	$ 31	$ (141)

Commitments and Contingencie112

Commitments and Contingencies (Commitments Textual) (Details) - SCE $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)contractagreement	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Costs incurred for power purchase agreements	$ 3,300	$ 3,200	$ 3,800
Operating leases expense	$ 68	80	96
Renewable Energy Contracts
Unrecorded Unconditional Purchase Obligation [Line Items]
Renewable energy contracts (number) | contract	119
Signed contracts, due in next twelve months	$ 1,516
Signed contracts, due within two years	1,606
Signed contracts, due within three years	1,704
Signed contracts, due within four years	1,776
Signed contracts, due within five years	1,786
Signed contracts, due after five years	$ 22,811
Qualifying Facility Power Purchase Agreements
Unrecorded Unconditional Purchase Obligation [Line Items]
QF contracts (number) | contract	55
Signed contracts, due in next twelve months	$ 187
Signed contracts, due within two years	148
Signed contracts, due within three years	87
Signed contracts, due within four years	39
Signed contracts, due within five years	16
Signed contracts, due after five years	$ 53
Combined Heat and Power Contracts
Unrecorded Unconditional Purchase Obligation [Line Items]
Heat and power contracts (number) | agreement	30
Other Power Purchase Agreements
Unrecorded Unconditional Purchase Obligation [Line Items]
Signed contracts, due in next twelve months	$ 769
Signed contracts, due within two years	604
Signed contracts, due within three years	516
Signed contracts, due within four years	472
Signed contracts, due within five years	420
Signed contracts, due after five years	1,258
Signed contracts, not meeting critical contract provisions
Unrecorded Unconditional Purchase Obligation [Line Items]
Signed contracts, due in next twelve months	53
Signed contracts, due within two years	235
Signed contracts, due within three years	312
Signed contracts, due within four years	554
Signed contracts, due within five years	630
Signed contracts, due after five years	9,100
Other contractual obligations
Unrecorded Unconditional Purchase Obligation [Line Items]
Cost incurred for other commitments	141	182	90
Other commitments due in next twelve months	156
Other commitments due in second year	141
Other commitments due in third year	103
Other commitments due in fourth year	98
Other commitments due in fifth year	82
Other commitments due after fifth year	631
Other contractual obligations not meeting critical contract provisions
Unrecorded Unconditional Purchase Obligation [Line Items]
Other commitments due in next twelve months	3
Other commitments due in second year	24
Other commitments due in third year	94
Other commitments due in fourth year	93
Other commitments due in fifth year	71
Other commitments due after fifth year	478
Operating Leases Purchase Power Contracts
Unrecorded Unconditional Purchase Obligation [Line Items]
Net operating leases expense	1,900	1,700	1,700
Contingent operating lease expense	1,400	1,100	944
Contingent capital lease expense	$ 109	$ 1	$ 1

Commitments and Contingencie113

Commitments and Contingencies (Undiscounted Future Minimum Expected Payments for Power Purchase Agreements) (Details) - SCE $ in Millions	Dec. 31, 2016USD ($)
Renewable Energy Contracts
Unrecorded Unconditional Purchase Obligation [Line Items]
2,017	$ 1,516
2,018	1,606
2,019	1,704
2,020	1,776
2,021	1,786
Thereafter	22,811
Total future commitments	31,199
Qualifying Facility Power Purchase Agreements
Unrecorded Unconditional Purchase Obligation [Line Items]
2,017	187
2,018	148
2,019	87
2,020	39
2,021	16
Thereafter	53
Total future commitments	530
Other Power Purchase Agreements
Unrecorded Unconditional Purchase Obligation [Line Items]
2,017	769
2,018	604
2,019	516
2,020	472
2,021	420
Thereafter	1,258
Total future commitments	$ 4,039

Commitments and Contingencie114

Commitments and Contingencies (Power Purchase Agreement - Operating and Capital Leases) (Details) - Southern California Edison Company $ in Millions	Dec. 31, 2016USD ($)
Operating Leases
Operating Leases
2,017	$ 341
2,018	237
2,019	161
2,020	146
2,021	142
Thereafter	1,355
Total future commitments	2,382
Capital Leases
Capital Leases
2,017	1
2,018	1
2,019	1
2,020	2
2,021	2
Thereafter	9
Total future commitments	16
Amount representing executory costs	(7)
Amount representing interest	(2)
Net commitments	$ 7

Commitments and Contingencie115

Commitments and Contingencies (Other Lease Commitments) (Details) - SCE - Operating Leases – Other $ in Millions	Dec. 31, 2016USD ($)
Operating Leased Assets [Line Items]
2,017	$ 52
2,018	46
2,019	37
2,020	28
2,021	22
Thereafter	258
Total future commitments	$ 443

Commitments and Contingencie116

Commitments and Contingencies (Other Commitments) (Details) - SCE - Other contractual obligations $ in Millions	Dec. 31, 2016USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
2,017	$ 156
2,018	141
2,019	103
2,020	98
2,021	82
Thereafter	631
Total	$ 1,211

Commitments and Contingencie117

Commitments and Contingencies (San Onofre CPUC Proceedings) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets	$ 7,455	$ 7,512
SCE
Regulatory Assets [Line Items]
Regulatory assets	7,455	7,512
San Onofre | SCE
Regulatory Assets [Line Items]
Regulatory assets	$ 857	$ 1,043

Commitments and Contingencie118

Commitments and Contingencies (MHI Claims) (Details)	Apr. 30, 2013USD ($)invoice	Oct. 31, 2013USD ($)	Jun. 30, 2010USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2012USD ($)
SCE
Jointly Owned Utility Plant Interests [Line Items]
Damages sought			$ 112,000,000
SCE | San Onofre | Mitsubishi Heavy Industries Ltd
Jointly Owned Utility Plant Interests [Line Items]
Invoices for reimbursement (number) | invoice	7
Invoices for repair costs	$ 149,000,000
Invoice paid for repair costs	$ 45,000,000
SCE portion of invoice paid for repair costs					$ 35,000,000
SCE | San Onofre | Mitsubishi Heavy Industries Ltd | Minimum
Jointly Owned Utility Plant Interests [Line Items]
Damages sought		$ 4,000,000,000
SCE | San Onofre | Mitsubishi Heavy Industries Ltd
Jointly Owned Utility Plant Interests [Line Items]
Allocated to customer (percent)				50.00%
SCE allocation (percent)				50.00%
Customers' portion of recoveries				$ 282,000,000
SCE | San Onofre | Replacement Steam Generators
Jointly Owned Utility Plant Interests [Line Items]
Warranty period				20 years
Mitsubishi Heavy Industries Ltd | San Onofre
Jointly Owned Utility Plant Interests [Line Items]
Stated liability under the purchase agreement				$ 138,000,000
Asserted counter claim		$ 41,000,000

Commitments and Contingencie119

Commitments and Contingencies (Environmental Remediation) (Details) - SCE $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)site	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Identified material sites (number) | site	19
Minimum estimated liability	$ 1
Recorded estimated minimum liability	$ 131
Immaterial sites (number) | site	18
Environmental remediation regulatory assets	$ 126
Expected recovery from incentive mechanism	$ 46
Expected recovery from incentive mechanism (percent)	90.00%
Recovery through customer rates	$ 80
Recovery through customer rates (percent)	100.00%
Cost may exceed recorded liability, material sites	$ 168
Cost may exceed recorded liability, immaterial sites	$ 8
Clean up (period)	30 years
Expected remediation costs for each of the next four years, low end of range	$ 8
Expected remediation costs for each of the next four years, high end of range	20
Environmental remediation expense	4	$ 5	$ 4
San Onofre
Jointly Owned Utility Plant Interests [Line Items]
Recorded estimated minimum liability	77
Material sites
Jointly Owned Utility Plant Interests [Line Items]
Recorded estimated minimum liability	128
Immaterial sites | Minimum
Jointly Owned Utility Plant Interests [Line Items]
Recorded estimated minimum liability	$ 3

Commitments and Contingencie120

Commitments and Contingencies (Nuclear Insurance) (Details) - Insurance Claims	12 Months Ended
	Dec. 31, 2016USD ($)
Loss Contingencies [Line Items]
Federal loss limit, bodily injury and property damage from nuclear incident	$ 13,400,000,000
SCE and other owners of San Onofre and Palo Verde | San Onofre and Palo Verde
Loss Contingencies [Line Items]
Maximum private primary insurance	450,000,000
ANI Facility Form coverage aggregate limit	450,000,000
Minimum federal requirement of nuclear property insurance	1,060,000,000
SCE
Loss Contingencies [Line Items]
Maximum assessment per each nuclear incident	255,000,000
Maximum yearly assessment per nuclear incident	38,000,000
Limit on assessment of retrospective premium adjustments, per year, approximate	$ 52,000,000

Commitments and Contingencie121

Commitments and Contingencies (Wildfire Insurance) (Details) - SCE $ in Millions	Dec. 31, 2016USD ($)
Loss Contingencies [Line Items]
Threshold for wildfire claims	$ 1,000
Self insurance retention per wildfire occurrence	$ 10

Commitments and Contingencie122

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

Preferred and Preference Sto123

Preferred and Preference Stock of Utility (Textual) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Preferred and Preference Stock
Preferred and Preference Stock of Utility
Preferred stock, shares issued	0	0	0
Preferred stock, shares redeemed	0	0	0
Dividends payable	$ 12	$ 14	$ 18
SCE | Cumulative preferred stock $100 par value
Preferred and Preference Stock of Utility
Preferred stock, par value (in dollars per share)	$ 100
Preferred stock, shares authorized	12,000,000
SCE | Cumulative preferred stock $25 par value
Preferred and Preference Stock of Utility
Preferred stock, par value (in dollars per share)	$ 25
Preferred stock, shares authorized	24,000,000
SCE | No par value:
Preferred and Preference Stock of Utility
Preferred stock, shares authorized	50,000,000
SCE | Preferred and Preference Stock
Preferred and Preference Stock of Utility
Dividends payable	$ 12	$ 14	$ 18
SCE | 5.45% Series K (cumulative)
Preferred and Preference Stock of Utility
Issuance of preference stock, during the period, value	$ 125

Preferred and Preference Sto124

Preferred and Preference Stock of Utility (Schedule of Preferred and Preference Stock) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Preferred and Preference Stock of Utility
Edison International's preferred and preference stock of utility	$ 2,191	$ 2,020
SCE
Preferred and Preference Stock of Utility
Edison International's preferred and preference stock of utility	$ 2,245	2,070
SCE | 4.08% Series
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	4.08%
Shares Outstanding	650,000
Redemption Price (in dollars per share)	$ 25.5
Preferred stock before issuance costs	$ 16	16
SCE | 4.24% Series
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	4.24%
Shares Outstanding	1,200,000
Redemption Price (in dollars per share)	$ 25.8
Preferred stock before issuance costs	$ 30	30
SCE | 4.32% Series
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	4.32%
Shares Outstanding	1,653,429
Redemption Price (in dollars per share)	$ 28.75
Preferred stock before issuance costs	$ 41	41
SCE | 4.78% Series
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	4.78%
Shares Outstanding	1,296,769
Redemption Price (in dollars per share)	$ 25.8
Preferred stock before issuance costs	$ 33	33
SCE | Preference stock
Preferred and Preference Stock of Utility
Preferred stock before issuance costs	2,245	2,070
Less issuance costs	(54)	(50)
Edison International's preferred and preference stock of utility	$ 2,191	2,020
SCE | 6.50% Series D (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	6.50%
Shares Outstanding	1,250,000
Redemption Price (in dollars per share)	$ 100
Preferred stock before issuance costs	$ 0	125
SCE | 6.25% Series E (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	6.25%
Shares Outstanding	350,000
Redemption Price (in dollars per share)	$ 1,000
Preferred stock before issuance costs	$ 350	350
SCE | 5.625% Series F (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	5.625%
Shares Outstanding	190,004
Redemption Price (in dollars per share)	$ 2,500
Preferred stock before issuance costs	$ 475	475
SCE | 5.10% Series G (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	5.10%
Shares Outstanding	160,004
Redemption Price (in dollars per share)	$ 2,500
Preferred stock before issuance costs	$ 400	400
SCE | 5.75% Series H (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	5.75%
Shares Outstanding	110,004
Redemption Price (in dollars per share)	$ 2,500
Preferred stock before issuance costs	$ 275	275
SCE | 5.375% Series J (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	5.375%
Shares Outstanding	130,004
Redemption Price (in dollars per share)	$ 2,500
Preferred stock before issuance costs	$ 325	325
SCE | 5.45% Series K (cumulative)
Preferred and Preference Stock of Utility
Preferred Stock, dividend rate, (as a percent)	5.45%
Shares Outstanding	120,004
Redemption Price (in dollars per share)	$ 2,500
Preferred stock before issuance costs	$ 300	$ 0

Accumulated Other Comprehens125

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension and PBOP – net gain (loss):
Other	$ 1	$ 0	$ 2
Accumulated Other Comprehensive Loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(56)	(58)
Pension and PBOP – net gain (loss):
Ending balance	(53)	(56)	(58)
Accumulated Defined Benefit Plans Adjustment
Pension and PBOP – net gain (loss):
Other comprehensive (loss) income before reclassifications	(4)	(8)
Reclassified from accumulated other comprehensive loss	6	10
Other	1	0
Change	3	2
SCE
Pension and PBOP – net gain (loss):
Other	1	0	2
SCE | Accumulated Other Comprehensive Loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(22)	(28)
Pension and PBOP – net gain (loss):
Ending balance	(20)	(22)	$ (28)
SCE | Accumulated Defined Benefit Plans Adjustment
Pension and PBOP – net gain (loss):
Other comprehensive (loss) income before reclassifications	(2)	1
Reclassified from accumulated other comprehensive loss	3	5
Other	1	0
Change	$ 2	$ 6

Interest and Other Income an126

Interest and Other Income and Other Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
SCE interest and other income:
Total Edison International interest and other income	$ 123	$ 174	$ 147
SCE other expenses:
Total Edison International other expenses	(44)	(59)	(80)
SCE
SCE interest and other income:
Equity allowance for funds used during construction	74	87	65
Increase in cash surrender value of life insurance policies and life insurance benefits	39	26	36
Interest income	3	4	5
Other	7	6	16
Total SCE interest and other income	123	123	122
Total Edison International interest and other income	123	123	122
SCE other expenses:
Civic, political and related activities and donations	(32)	(35)	(35)
Other	(12)	(24)	(44)
Total SCE other expenses	(44)	(59)	(79)
Total Edison International other expenses	(44)	(59)	(79)
Edison International Parent and Other
SCE interest and other income:
Other income of Edison International Parent and Other1	0	51	25
SCE other expenses:
Other expense of Edison International Parent and Other	$ 0	$ 0	$ (1)

Discontinued Operations (Detail

Discontinued Operations (Details) $ in Millions	1 Months Ended		3 Months Ended								12 Months Ended
	Aug. 31, 2014installment	Apr. 30, 2014USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of tax			$ 13	$ 0	$ (2)	$ 1	$ (8)	$ 43	$ 0	$ 0	$ 12	$ 35	$ 185
Income (loss) before income taxes											1	15	(525)
Income tax benefits											(11)	(21)	(710)
Edison Mission Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash portion of settlement payment		$ 225
Number of installments | installment	2
Installment one, tax attribute settlement								$ 204
Installment two, tax attribute settlement				$ 214
Edison International
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of tax											$ 12	$ 35	185
Income tax benefits													$ (710)

Supplemental Cash Flows Info128

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash payments (receipts) for interest and taxes:
Interest, net of amounts capitalized	$ 504	$ 512	$ 504
Tax payments (refunds), net	18	1	32
Details of debt exchange:
Pollution-control bonds redeemed (2.875%)	0	(203)	0
Pollution-control bonds issued (1.875%)	0	203	0
Notes issued under EME Settlement Agreement	0	0	418
Common Stock
Non-cash financing and investing activities:
Dividends declared but not paid	177	156	136
Preference stock
Non-cash financing and investing activities:
Dividends declared but not paid	$ 12	$ 14	$ 18
2.875% Pollution-Control Bonds
Details of debt exchange:
Interest rate on converted debt	2.875%	2.875%	2.875%
1.875% Pollution-Control Bonds Due in 2029
Details of debt exchange:
Interest rate on converted debt	1.875%	1.875%	1.875%
SCE
Cash payments (receipts) for interest and taxes:
Interest, net of amounts capitalized	$ 475	$ 478	$ 487
Tax payments (refunds), net	78	144	(88)
Details of debt exchange:
Pollution-control bonds redeemed (2.875%)	0	(203)	0
Pollution-control bonds issued (1.875%)	0	203	0
Notes issued under EME Settlement Agreement	0	0	0
Accrued capital expenditures	540	543	837
Reduction in lease obligation		147
SCE | Common Stock
Non-cash financing and investing activities:
Dividends declared but not paid	0	0	147
SCE | Preference stock
Non-cash financing and investing activities:
Dividends declared but not paid	$ 12	$ 14	$ 18
SCE | 2.875% Pollution-Control Bonds
Details of debt exchange:
Interest rate on converted debt	2.875%	2.875%	2.875%
SCE | 1.875% Pollution-Control Bonds Due in 2029
Details of debt exchange:
Interest rate on converted debt	1.875%	1.875%	1.875%

Quarterly Financial Data (Un129

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Financial Data [Line Items]
Total operating revenue	$ 2,884	$ 3,767	$ 2,777	$ 2,440	$ 2,341	$ 3,763	$ 2,908	$ 2,512	$ 11,869	$ 11,524	$ 13,413
Operating income	566	695	381	448	340	608	524	538	2,092	2,008	2,472
Net income									1,425	1,117	1,721
Income (loss) from continuing operations	347	451	310	305	(47)	405	406	318	1,413	1,082	1,536
Income (loss) from discontinued operations, net	13	0	(2)	1	(8)	43	0	0	12	35	185
Net income (loss) attributable to common shareholders	$ 329	$ 421	$ 280	$ 281	$ (79)	$ 421	$ 379	$ 299	$ 1,311	$ 1,020	$ 1,612
Basic earnings per share – continuing operations:
Continuing operations (in dollars per share)	$ 0.97	$ 1.29	$ 0.87	$ 0.86	$ (0.22)	$ 1.16	$ 1.16	$ 0.92	$ 3.99	$ 3.02	$ 4.38
Discontinued operations (in dollars per share)	0.04	0	(0.01)	0	(0.02)	0.13	0	0	0.03	0.11	0.57
Total (in dollars per share)	1.01	1.29	0.86	0.86	(0.24)	1.29	1.16	0.92	4.02	3.13	4.95
Diluted earnings per share – continuing operations:
Continuing operations (in dollars per share)	0.96	1.27	0.86	0.85	(0.22)	1.15	1.15	0.91	3.94	2.99	4.33
Diluted earnings (loss) per share – discontinued operations (in dollars per share)	0.04	0	(0.01)	0	(0.02)	0.13	0	0	0.03	0.11	0.56
Total (in dollars per share)	1	1.27	0.85	0.85	(0.24)	1.28	1.15	0.91	3.97	3.10	4.89
Dividends declared per common share (in dollars per share)	0.5425	0.4800	0.4800	0.4800	0.48	0.4175	0.4175	0.4175	1.9825	1.7325	$ 1.4825
Common stock prices:
High (in dollars per share)	73.81	78.72	77.71	72.34	66.29	63.18	64.55	69.59	78.72	69.59
Low (in dollars per share)	67.44	71.31	67.71	57.97	57.51	55.52	55.18	61.02	57.97	55.18
Close (in dollars per share)	$ 71.99	$ 72.25	$ 77.67	$ 71.89	$ 59.21	$ 63.07	$ 55.58	$ 62.47	$ 71.99	$ 59.21
Disallowance of Repair Allowance Deduction
Common stock prices:
Income tax charge (benefit)											$ (133)
As reported in Form 10-Q filings
Quarterly Financial Data [Line Items]
Income (loss) from continuing operations		$ 449	$ 306	$ 295
Net income (loss) attributable to common shareholders		$ 419	$ 276	$ 271
Basic earnings per share – continuing operations:
Continuing operations (in dollars per share)		$ 1.29	$ 0.86	$ 0.83
Diluted earnings per share – continuing operations:
Continuing operations (in dollars per share)		$ 1.27	$ 0.85	$ 0.82
SCE
Quarterly Financial Data [Line Items]
Total operating revenue	$ 2,874	$ 3,752	$ 2,768	$ 2,435	$ 2,319	$ 3,757	$ 2,901	$ 2,508	$ 11,830	$ 11,485	13,380
Operating income	594	721	429	472	366	626	536	550	2,217	2,080	2,529
Net income	359	466	349	325	(51)	417	412	333	1,499	1,111	1,565
Net income (loss) attributable to common shareholders	328	435	318	295	(80)	389	384	305	1,376	998	$ 1,453
Common stock prices:
Common dividends declared	$ 191	170	170	170	170	$ 147	$ 147	$ 147	$ 701	611
SCE | Disallowance of Repair Allowance Deduction
Common stock prices:
Income tax charge (benefit)					$ 382					$ 382
SCE | As reported in Form 10-Q filings
Quarterly Financial Data [Line Items]
Net income		466	346	317
Net income (loss) attributable to common shareholders		$ 435	$ 315	$ 287

Schedule I - Condensed Finan130

Schedule I - Condensed Financial Information of Parent (Details)	3 Months Ended								12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Assets:
Cash and cash equivalents	$ 96,000,000			$ 161,000,000	$ 161,000,000			$ 132,000,000	$ 161,000,000	$ 132,000,000	$ 146,000,000	$ 96,000,000	$ 161,000,000	$ 132,000,000	$ 146,000,000
Other current assets												281,000,000	251,000,000
Total current assets												2,123,000,000	2,654,000,000
Other long-term assets												415,000,000	360,000,000
Total assets												51,319,000,000	50,229,000,000
Liabilities and equity:
Short-term debt												1,307,000,000	695,000,000
Current portion of long-term debt												981,000,000	295,000,000
Other current liabilities												991,000,000	967,000,000
Total current liabilities												5,912,000,000	4,927,000,000
Long-term debt												10,175,000,000	10,883,000,000
Total equity												14,187,000,000	13,388,000,000	12,982,000,000	11,691,000,000
Total liabilities and equity												51,319,000,000	$ 50,229,000,000
Condensed Statements of Income:
Interest income from affiliates	2,884,000,000	$ 3,767,000,000	$ 2,777,000,000	2,440,000,000	2,341,000,000	$ 3,763,000,000	$ 2,908,000,000	2,512,000,000	11,869,000,000	11,524,000,000	13,413,000,000
Operating expenses and interest expense									9,777,000,000	9,516,000,000	10,941,000,000
Operating income (loss)	566,000,000	695,000,000	381,000,000	448,000,000	340,000,000	608,000,000	524,000,000	538,000,000	2,092,000,000	2,008,000,000	2,472,000,000
Income tax benefit									177,000,000	486,000,000	443,000,000
Income from continuing operations	347,000,000	451,000,000	310,000,000	305,000,000	(47,000,000)	405,000,000	406,000,000	318,000,000	1,413,000,000	1,082,000,000	1,536,000,000
Income from discontinued operations, net of tax	13,000,000	0	(2,000,000)	1,000,000	(8,000,000)	43,000,000	0	0	12,000,000	35,000,000	185,000,000
Condensed Statements of Comprehensive Income
Other comprehensive income (loss), net of tax									3,000,000	2,000,000	(45,000,000)
Comprehensive income									1,314,000,000	1,022,000,000	1,567,000,000
Condensed Statements of Cash Flows:
Net cash provided by (used in) operating activities									3,256,000,000	4,509,000,000	3,248,000,000
Cash flows from financing activities:
Long-term debt issued									397,000,000	1,420,000,000	494,000,000
Short-term debt financing, net									611,000,000	(572,000,000)	1,079,000,000
Dividends paid									(626,000,000)	(544,000,000)	(463,000,000)
Net cash (used in) provided by financing activities									95,000,000	(588,000,000)	645,000,000
Net cash used in investing activities									(3,416,000,000)	(3,892,000,000)	(3,907,000,000)
Net (decrease) increase in cash and cash equivalents									(65,000,000)	29,000,000	(14,000,000)
Cash and cash equivalents, beginning of year				161,000,000				132,000,000	161,000,000	132,000,000	146,000,000
Cash and cash equivalents, end of year	96,000,000				161,000,000				96,000,000	161,000,000	132,000,000
Senior Notes Due 2017
Debt and Credit Agreements
Interest rate on debt (as a percent)													3.75%
Multi-year credit facilities
Debt and Credit Agreements
Commitment												$ 1,250,000,000
Weighted average interest rate (as a percent)												0.97%	0.78%
Outstanding borrowings (outstanding commercial paper was $619 million at year-end)												$ (538,000,000)	$ (646,000,000)
Amount available												712,000,000
Senior notes | 2.95% Senior notes due 2023
Debt and Credit Agreements
Debt, face amount				$ 400,000,000
Interest rate on debt (as a percent)				2.95%
Edison International
Assets:
Cash and cash equivalents	6,000,000			$ 7,000,000	7,000,000			8,000,000	7,000,000	8,000,000	13,000,000	6,000,000	7,000,000	8,000,000	13,000,000
Other current assets												261,000,000	259,000,000
Total current assets												267,000,000	266,000,000
Investments in subsidiaries												13,459,000,000	12,696,000,000
Deferred income taxes												646,000,000	626,000,000
Other long-term assets												108,000,000	110,000,000
Total assets												14,480,000,000	13,698,000,000
Liabilities and equity:
Short-term debt												539,000,000	646,000,000
Current portion of long-term debt												400,000,000	214,000,000
Other current liabilities												484,000,000	368,000,000
Total current liabilities												1,423,000,000	1,228,000,000
Long-term debt												397,000,000	398,000,000
Other long-term liabilities												664,000,000	704,000,000
Total equity												11,996,000,000	11,368,000,000
Total liabilities and equity												14,480,000,000	13,698,000,000
Condensed Statements of Income:
Interest income from affiliates									6,000,000	3,000,000	3,000,000
Operating expenses and interest expense									86,000,000	78,000,000	94,000,000
Operating income (loss)									(80,000,000)	(75,000,000)	(91,000,000)
Equity in earnings of subsidiaries									1,337,000,000	1,025,000,000	1,482,000,000
Income before income taxes									1,257,000,000	950,000,000	1,391,000,000
Income tax benefit									(42,000,000)	(35,000,000)	(36,000,000)
Income from continuing operations									1,299,000,000	985,000,000	1,427,000,000
Income from discontinued operations, net of tax									12,000,000	35,000,000	185,000,000
Net income									1,311,000,000	1,020,000,000	1,612,000,000
Condensed Statements of Comprehensive Income
Net income									1,311,000,000	1,020,000,000	1,612,000,000
Other comprehensive income (loss), net of tax									3,000,000	2,000,000	(45,000,000)
Comprehensive income									1,314,000,000	1,022,000,000	1,567,000,000
Condensed Statements of Cash Flows:
Net cash provided by (used in) operating activities									493,000,000	641,000,000	(73,000,000)
Cash flows from financing activities:
Long-term debt issued									400,000,000	0	0
Long-term debt issuance costs									(3,000,000)	0	0
Payable due to affiliates									34,000,000	54,000,000	66,000,000
Short-term debt financing, net									(108,000,000)	26,000,000	584,000,000
Settlements of stock-based compensation, net									(44,000,000)	(42,000,000)	(24,000,000)
Dividends paid									(626,000,000)	(544,000,000)	(463,000,000)
Net cash (used in) provided by financing activities									(347,000,000)	(506,000,000)	163,000,000
Capital contributions to affiliate									(147,000,000)	(30,000,000)	(35,000,000)
Loans to affiliate									0	(106,000,000)	(60,000,000)
Net cash used in investing activities									(147,000,000)	(136,000,000)	(95,000,000)
Net (decrease) increase in cash and cash equivalents									(1,000,000)	(1,000,000)	(5,000,000)
Cash and cash equivalents, beginning of year				7,000,000				8,000,000	7,000,000	8,000,000	13,000,000
Cash and cash equivalents, end of year	6,000,000				7,000,000				6,000,000	7,000,000	8,000,000
Basis of Presentation
Cash dividends received from consolidated subsidiaries									701,000,000	758,000,000	378,000,000
Related Party Transactions
Current receivables due from affiliates												262,000,000	252,000,000
Current payables due to affiliates												221,000,000	149,000,000
Long-term receivables due from affiliate												103,000,000	105,000,000
Long-term payables due to affiliates												$ 243,000,000	213,000,000
Edison International | Senior Notes Due 2017
Debt and Credit Agreements
Interest rate on debt (as a percent)												3.75%
Senior notes												$ 400,000,000	400,000,000
Edison International | Credit Facility July 2020
Debt and Credit Agreements
Commitment		1,250,000,000
Edison International | Revolving credit facility maturing in July 2018
Debt and Credit Agreements
Amount available												$ 712,000,000
Covenant requirement, consolidated debt to total capitalization, ratio												0.65
Consolidated debt to total capitalization, ratio												0.47
Edison International | SCE
Related Party Transactions
Expenses from services provided by SCE									3,000,000	3,000,000	3,000,000
Interest expense from loans due to affiliates									3,000,000	6,000,000	1,000,000
SCE
Assets:
Cash and cash equivalents	39,000,000			26,000,000	26,000,000			38,000,000	26,000,000	38,000,000	54,000,000	$ 39,000,000	26,000,000	38,000,000	54,000,000
Other current assets												262,000,000	234,000,000
Total current assets												2,031,000,000	2,443,000,000
Other long-term assets												231,000,000	239,000,000
Total assets												50,891,000,000	49,795,000,000
Liabilities and equity:
Short-term debt												769,000,000	49,000,000
Current portion of long-term debt												579,000,000	79,000,000
Other current liabilities												729,000,000	760,000,000
Total current liabilities												4,707,000,000	3,821,000,000
Long-term debt												9,754,000,000	10,460,000,000
Total equity												14,483,000,000	13,672,000,000	$ 13,282,000,000	$ 12,138,000,000
Total liabilities and equity												50,891,000,000	$ 49,795,000,000
Condensed Statements of Income:
Interest income from affiliates	2,874,000,000	3,752,000,000	2,768,000,000	2,435,000,000	2,319,000,000	3,757,000,000	2,901,000,000	2,508,000,000	11,830,000,000	11,485,000,000	13,380,000,000
Operating expenses and interest expense									9,613,000,000	9,405,000,000	10,851,000,000
Operating income (loss)	594,000,000	$ 721,000,000	$ 429,000,000	472,000,000	366,000,000	$ 626,000,000	$ 536,000,000	550,000,000	2,217,000,000	2,080,000,000	2,529,000,000
Income tax benefit									256,000,000	507,000,000	474,000,000
Condensed Statements of Comprehensive Income
Other comprehensive income (loss), net of tax									2,000,000	6,000,000	(17,000,000)
Condensed Statements of Cash Flows:
Net cash provided by (used in) operating activities									3,523,000,000	4,624,000,000	3,660,000,000
Cash flows from financing activities:
Long-term debt issued									0	1,413,000,000	498,000,000
Short-term debt financing, net									719,000,000	(619,000,000)	490,000,000
Dividends paid									(824,000,000)	(874,000,000)	(489,000,000)
Net cash (used in) provided by financing activities									(219,000,000)	(812,000,000)	181,000,000
Net cash used in investing activities									(3,291,000,000)	(3,824,000,000)	(3,857,000,000)
Net (decrease) increase in cash and cash equivalents									13,000,000	(12,000,000)	(16,000,000)
Cash and cash equivalents, beginning of year				$ 26,000,000				$ 38,000,000	26,000,000	38,000,000	54,000,000
Cash and cash equivalents, end of year	$ 39,000,000				$ 26,000,000				$ 39,000,000	$ 26,000,000	$ 38,000,000
Basis of Presentation
Minimum percentage of weighted-average common equity component authorization, set by CPUC (as a percent)									48.00%
Weighted-average common equity component authorization, set by CPUC remaining over number of months (in months)									13 months
Period for calculation of weighted average common equity component (months)									13 months
Weighted-average common equity component of total capitalization (as a percent)									50.40%
Capacity to pay additional dividends									$ 585,000,000
Restriction on net assets												13,900,000,000
SCE | Multi-year credit facilities
Debt and Credit Agreements
Commitment												2,750,000,000
Outstanding borrowings (outstanding commercial paper was $619 million at year-end)												(769,000,000)
Amount available												$ 1,890,000,000

Schedule II - Valuation and 131

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	$ 61.7	$ 72.2	$ 70
Charged to Costs and Expenses	33.6	41.9	43.8
Charged to Other Accounts	0	0	0
Deductions	33.5	52.4	41.6
Balance at End of Period	61.8	61.7	72.2
Deferred tax assets, loss and credit carryforwards	1,418	1,388		$ 2,200
Customers
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	46.2	48.9	52.2
Charged to Costs and Expenses	17.7	23.9	24.1
Charged to Other Accounts	0	0	0
Deductions	22.7	26.6	27.4
Balance at End of Period	41.2	46.2	48.9
All others
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	15.5	23.3	17.8
Charged to Costs and Expenses	15.9	18	19.7
Charged to Other Accounts	0	0	0
Deductions	10.8	25.8	14.2
Balance at End of Period	20.6	15.5	23.3
Tax valuation allowance
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	32	29	1,380
Charged to Costs and Expenses	0	3	0
Charged to Other Accounts	0	0	0
Deductions	8	0	1,351
Balance at End of Period	24	32	29
Edison Mission Energy
Movement in Valuation and Qualifying Accounts
Deferred tax assets, loss and credit carryforwards				1,600
Deferred income tax benefits, net				$ 220
Southern California Edison Company
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	61.7	67.6	65.5
Charged to Costs and Expenses	32.9	41.9	43.7
Charged to Other Accounts	0	0	0
Deductions	33.5	47.8	41.6
Balance at End of Period	61.1	61.7	67.6
Deferred tax assets, loss and credit carryforwards	0	0
Southern California Edison Company | Customers
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	46.2	48.9	52.2
Charged to Costs and Expenses	17	23.9	24.1
Charged to Other Accounts	0	0	0
Deductions	22.7	26.6	27.4
Balance at End of Period	40.5	46.2	48.9
Southern California Edison Company | All others
Movement in Valuation and Qualifying Accounts
Balance at Beginning of Period	15.5	18.7	13.3
Charged to Costs and Expenses	15.9	18	19.6
Charged to Other Accounts	0	0	0
Deductions	10.8	21.2	14.2
Balance at End of Period	$ 20.6	$ 15.5	$ 18.7